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Home My WebLink About201-2121. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Tubing Patch Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 13402'feet None feet true vertical 7138' feet None feet Effective Depth measured 13402'feet 4159', 4181', 9229'feet true vertical 7138' feet 3371', 3387', 6991'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 9417' MD 7045' TVD Packers and SSSV (type, measured and true vertical depth) 4159' MD 4181' MD 9229' MD N/A 3371' TVD 3387' TVD 6991' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Alpine Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 275 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: PIIP Patch Packer Packer: PIIP Patch Packer Packer: Baker S-3 Packer SSSV: None Kate Dodson kate.dodson@conocophillips.com (907) 265-6181Senior Well Interventions Engineer Open Hole: 9972-13402' Open Hole: 7167-7138' measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 215 Gas-Mcf MD 1990 Size 114' 2500 1675640 135 205925 225 measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 201-212 50-103-20395-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025559, ADL0380075 Colville River Field/ Alpine Oil Pool CRU CD2-45 Plugs Junk measured Length Production Liner 9937' Casing 7167'9972' 2728' 114'Conductor Surface Intermediate 16" 9-5/8" 77' 2764' 2382' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 1:51 pm, Aug 05, 2024 Digitally signed by Kate Dodson DN: OU=Wells, O=ConocoPhillips, CN=Kate Dodson, E=kate.dodson@ conocophillips.com Reason: I am the author of this document Location: Date: 2024.08.05 09:44:49-08'00' Foxit PDF Editor Version: 13.0.0 Kate Dodson DTTMSTART JOBTYP SUMMARYOPS 7/8/2024 REPAIR WELL RIG UP ELINE TO SET QUADCO PARAGON 2 PACKER LOWER ANCHOR FOR PATCH. PACKER SETTING DEPTH = 4184', CCL TO MID ELEMENT = 10.0', CCL STOP DEPTH = 4174.0'. JOB COMPLETE, READY FOR SLICKLINE. 7/12/2024 REPAIR WELL SET UPPER PACKER, 22' SPACER PIPE & ANCHOR LATCH W/ MID ELEMENT @ 4162' RKB (TOP @ 4159' RKB); SET 4.5" TTS TEST TOOL & PERFORMED PASSING MITT TO 2500 PSI, PULLED 4.5" TEST TOOL; DRIFTED TBG W/ 3.85" TO BAL-O NIP @ 2231' RKB; SET 3.81" DB LOCK W/ 4.5" ISO SLEEVE (OAL = 55", ID = 2.50"). JOB COMPLETE. 7/20/2024 REPAIR WELL (AC EVAL) RE TIFL PASSED CD2-45 Patch Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: CD2-45 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set Patch CD2-45 7/13/2024 kdodson Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 14.69 37.0 114.0 114.0 109.00 H-40 WELD SURFACE 9 5/8 8.92 36.6 2,764.3 2,382.3 36.00 J-55 BTC PRODUCTION 7 6.28 34.5 9,972.0 7,167.0 26.00 L-80 BTCM OPEN HOLE 6 1/8 6.13 9,972.0 13,402.0 7,137.9 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 32.5 Set Depth 9,416.9 Set Depth 7,044.8 String Max No 4 1/2 Tubing Description TUBING Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 32.5 32.5 0.00 HANGER 10.800 FMC TUBING HANGER 4.500 2,231.6 2,014.7 46.68 NIPPLE 6.062 CAMCO BAL-O NIPPLE CAMCO BAL-O 3.812 4,170.4 3,379.1 44.78 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 7,422.7 5,696.4 44.37 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 9,073.6 6,861.5 51.07 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 9,187.4 6,930.5 54.72 SLEEVE 5.000 BAKER CMD SLIDING SLEEVE (C) w/ 3.813" 'BX' PROFILE BAKER CMD 3.813 9,299.1 6,990.7 60.30 PACKER 5.970 BAKER S-3 PACKER w/ MILLOUT EXTENSION BAKER S-3 3.875 9,404.6 7,039.4 63.83 NIPPLE 5.000 HES XN NIPPLE HES XN 3.725 9,415.6 7,044.2 64.06 WLEG 5.000 BAKER WIRELINE GUIDE 3.875 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 4,158.9 3,371.0 44.81 PACKER - PATCH - UPR 4-1/2" Paragon II Packer, ME @ 4162' RKB. OAL= 22.031ft Paragon PIIP ALPP 45014 7/12/2024 2.000 4,162.0 3,373.1 44.81 ANCHOR LATCH ON SPACER PIPE 3.650" Latch Seal Assembly with 2-3/8" spacer pipe ME to ME = 22.03ft Paragon PIIP ALPA L4501 6 7/12/2024 2.000 4,170.0 3,378.8 44.78 LEAK - TUBING Tubing leak 4,170' 5/15/2023 0.000 4,180.9 3,386.6 44.75 PACKER - PATCH - LWR 4-1/2" Paragon II Packer, ME @ 4184' RKB, wilth lower WLEG, note standard 4.5 SDRT to retrieve OAL=4.3ft Paragon PIIP ALPP 45016 7/8/2024 2.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 4,170.4 3,379.1 44.78 1 GAS LIFT OPEN BK-5 1 4/11/2023 Patch Over 7,422.7 5,696.4 44.37 2 GAS LIFT GLV BK-5 1 1,737.0 4/11/2023 0.188 9,073.6 6,861.5 51.07 3 GAS LIFT OV BK-5 1 0.0 4/10/2023 0.250 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,972.0 7,167.0 90.25 OPEN HOLE 6.125 6.125 CD2-45, 7/30/2024 2:52:16 PM Vertical schematic (actual) OPEN HOLE; 9,972.0-13,402.0 PRODUCTION; 34.5-9,972.0 FLOAT SHOE; 9,970.3-9,972.0 FLOAT COLLAR; 9,885.7- 9,887.1 WLEG; 9,415.5 NIPPLE; 9,404.6 PACKER; 9,299.0 SLEEVE; 9,187.4 GAS LIFT; 9,073.6 GAS LIFT; 7,422.7 PACKER - PATCH - LWR; 4,180.9 GAS LIFT; 4,170.4 ANCHOR LATCH ON SPACER PIPE; 4,162.0 LEAK - TUBING; 4,170.0 PACKER - PATCH - UPR; 4,158.9 SURFACE; 36.6-2,764.3 FLOAT SHOE; 2,762.6-2,764.3 FLOAT COLLAR; 2,677.2- 2,678.8 NIPPLE; 2,231.6 CONDUCTOR; 37.0-114.0 HANGER; 36.6-38.9 HANGER; 34.5-36.1 HANGER; 32.5 WNS PROD KB-Grd (ft) 44.10 RR Date 11/29/200 3 Other Elev CD2-45 ... TD Act Btm (ftKB) 13,402.0 Well Attributes Field Name ALPINE Wellbore API/UWI 501032039500 Wellbore Status PROD Max Angle & MD Incl (°) 92.96 MD (ftKB) 12,517.62 WELLNAME WELLBORECD2-45 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: WRDP Originated: Delivered to:22-Jul-24 Alaska Oil & Gas Conservation Commiss 22Jul24-NR ATTN: Meredith Guhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER #FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED 3S-03 50-103-20458-00-00 203-091 Kuparuk River WL Perf FINAL FIELD 27-Jun-24 CD2-45 50-103-20395-00-00 201-212 Colville River WL Patch FINAL FIELD 8-Jul-24 CD1-40 50-103-20298-00-00 199-044 Colville River WL LDL FINAL FIELD 10-Jul-24 CD4-24 50-103-20602-00-00 209-097 Colville River WL LDL FINAL FIELD 11-Jul-24 CD4-93A 50-103-20690-01-00 215-026 Colville River WL LDL FINAL FIELD 13-Jul-24 2W-01 50-029-21273-00-00 185-010 Kuparuk River WL LDL FINAL FIELD 16-Jul-24 Transmittal Receipt ________________________________ X_________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Nraasch@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private T39255 T39256 T39257 T39258 T39259 T39260 CD2-45 50-103-20395-00-00 201-212 Colville River WL Patch FINAL FIELD 8-Jul-24 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.22 10:48:54 -08'00' C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2024-05-17_22172_CRU_CD2-45_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22172 CRU CD2-45 50-103-20395-00 Caliper Survey w/ Log Data 17-Jun-24 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 201-212 T39053 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.26 15:05:00 -08'00' TTT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – CRU DATE: 12/19/2023 Transmitted: North Slope, Colville River Unit data drophard driveVia CD2-45 50-103-20395-00 201212_CD2-45_Patch_15May2023 CD2-53 50-103-20494-00 204089_CD2-53_LDL_30Nov2022 204089_CD2-53_Patch_14Oct2022 CD3-107 50-103-20529-01 206189_CD3-107_Packer_16Apr2022 CD3-125 50-103-20632-00 210189_CD3-125_LDL_23Feb23 210189_CD3-125_POGLM_03Apr2023 CD3-127 50-103-20634-00 211005_CD3-127_Patch_23Apr2022 211005_CD3-127_PPROF_18Apr2022 CD3-303 50-103-20568-00 208013_CD3-303_CHC_21Feb2023 CD4-499 50-103-20810-00 219161_CD4-499_PPROF_28Sep2023 WD-02 50-103-20285-00 198258_WD-02_WFL_22May2022 WD-03 50-103-20835-00 221103_WD-03_IBC DSLT_12Feb2022 221103_WD-03_USIT_28Feb2022 2 of 2 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38298 T38299 T38300 T38301 T38302 T38303 T38304 T38305 T38306 2/29/2024 CD2-45 50-103-20395-00 201212_CD2-45_Patch_15May2023 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 10:46:16 -09'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Tubing Patch Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 13402'feet None feet true vertical 7138'feet None feet Effective Depth measured 13402'feet 4160', 4182', 9299'feet true vertical 7138'feet 3372', 3387', 6991'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 9417' MD 7045' TVD Packers and SSSV (type, measured and true vertical depth) 4160' MD 4182' MD 9299' MD N/A 3372' TVD 3387' TVD 6991' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: P2P Patch Packer Packer: P2P Patch Packer Packer: Baker S-3 Packer SSSV: None Kate Dodson kate.dodson@conocophillips.com 265-6181Senior Well Interventions Engineer Open Hole: 9972-13402' Open Hole:7167'-7138' measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 368 BOPD Gas-Mcf MD ~ Size 114' 3202 BWPD 16341148 Well was Shut-In ~~ 227 measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 201-212 50-103-20395-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL0025559, ADL0380075 Colville River Field/ Alpine Oil Pool CRU CD2-45 Plugs Junk measured Length Production Liner 9937' Casing 7167'9972' 2728' 114'Conductor Surface Intermediate 16" 9-5/8" 77' 2764' 2382' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Kate Dodson DN: OU=Wells, O=ConocoPhillips, CN=Kate Dodson, E=kate.dodson@conocophillips.com Reason: Location: Date: 2023.06.21 09:50:17-08'00' Foxit PDF Editor Version: 12.1.2 Kate Dodson C DTTMSTART JOBTYP SUMMARYOPS 3/26/2023 ANNCOMM PULL RBP FROM 8905' RKB, ALL SEALS AND ELEMENTS INTACT. JOB IN PROGRESS. 3/27/2023 ANNCOMM DRY TAG @ 9038' CTMD, MILL DOWN TO 9350' SHUT DOWN PUMP DRY TAG NIPPLE AT 9404' OOH, MAKE UP ABRADO, WASH ACROSS PATCH SETTING DEPTH @ 4120'-4190' UP, DOWN, UP. OOH RDMO, WELL READY FOR SLICKLINE. 4/8/2023 ANNCOMM SHOOK FLAT BOTTOM CATCHER OFF @ 4900' SLM; ATTEMPT TO PULL OV FROM GLM #3 @ 9073' RKB, SAT DOWN @ 9012' SLM & UNABLE TO PASS. IN PROGRESS. 4/9/2023 ANNCOMM PULLED 4.5" FLAT BOTTOM CATCHER @ 9012' SLM; DRIFT TBG W/ 3.77" GAUGE RING TO XN NIP @ 9404' RKB; SET BAITED GAUGE RING (OAL = 62") ON XN NIP @ 9404' RKB; PULLED OV FROM GLM #3 @ 9073' RKB. IN PROGRESS. 4/10/2023 ANNCOMM PULLED BAITED GAUGE RING CATCHER @ 9404' RKB; LRS BULL HEADS 150 BBLs OF CRW & 40 BBLs OF DIESEL DOWN IA; SET BAITED GAUGE RING BACK @ 9404' RKB; SET 1" x .25" OV IN GLM #3 @ 9073' RKB; PULLED GLV FROM GLM #2 @ 7422' RKB; ATTEMPT TO SET GLV @ SAME, UNSUCCESSFUL. IN PROGRESS. 4/11/2023 ANNCOMM SET 1" GLV (TRO: 1737, PORT: 3/16") W/ BK LATCH IN GLM #2 @ 7422' RKB; PULLED 1" DMY VLV FROM GLM #1 @ 4170' RKB; PULLED BAITED GAUGE RING FROM 9404' RKB; SET HOLEFINDER @ 9157' RKB & 9139' RKB, UNABLE TO GET A CMIT; DRIFT TBG TO 4200' SLM W/ 4.5" RBP PATCH DUMMY DRIFT. JOB SUSPENDED FOR HIGHER PRIORITY WORK. IN PROGRESS. 5/11/2023 ANNCOMM RAN 3.81" D&D HOLEFINDER TO 9244' RKB. CMIT PASSED PU TO 9144' RKB CMIT FAIL. PU TO 9131' RKB. CMIT FAILED PU TO 9121' RKB. CMIT FAILED. IN PROGRESS. 5/12/2023 ANNCOMM RAN 3.81" D&D HF TO 9216' RKB. CMIT PASSED PU TO 9196' RKB CMIT PASSED. CMD CLOSED. PU TO 9062' RKB. CMIT FAILED. RE-RAN 3.81" D&D HF TO 9107' RKB. CMIT PASSED. READY FOR PATCH. IN PROGRESS. 5/15/2023 ANNCOMM SET QUADCO P2P LOWER PACKER FOR PATCH. LOWER PACKER SETTING DEPTH = 4185', CCL TO MID ELEMENT = 10.0' , CCL STOP DEPTH = 4175'. JOB COMPLETE, READY FOR SLICKLINE. 5/17/2023 ANNCOMM SET 4.5" PIIP PACKER, 16.82' SPACER PIPE W/ ANCHOR LATCH (OAL = 26.89'), TOP OF PACKER @ 4160' RKB, MID ELEMENT @ 4163' RKB. BLED IA TO 25 PSI, HOLDING. *in progress* 5/18/2023 ANNCOMM SET 3.81" DB LOCK W/ 4.5" ISO SLEEVE (OAL = 54"), GAIN C/L INTEGRITY. JOB COMPLETE. 5/31/2023 ANNCOMM (AC EVAL) RE TIFL PASSED CD2-45 Tubing Patch Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: CD2-45 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set Upper Patch, ISO Sleeve CD2-45 5/18/2023 rmoore22 Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 14.69 37.0 114.0 114.0 109.00 H-40 WELD SURFACE 9 5/8 8.92 36.6 2,764.3 2,382.3 36.00 J-55 BTC PRODUCTION 7 6.28 34.5 9,972.0 7,167.0 26.00 L-80 BTCM OPEN HOLE 6 1/8 6.13 9,972.0 13,402.0 7,137.9 Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 32.5 Set Depth 9,416.9 Set Depth 7,044.8 String Ma 4 1/2 Tubing Description TUBING Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 32.5 32.5 0.00 HANGER 10.800 FMC TUBING HANGER 4.500 2,231.6 2,014.7 46.68 NIPPLE 6.062 CAMCO BAL-O NIPPLE CAMCO BAL-O 3.812 4,170.4 3,379.1 44.78 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 7,422.7 5,696.4 44.37 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 9,073.6 6,861.5 51.07 GAS LIFT 5.984 CAMCO KBG-2 CAMCO KBG-2 3.938 9,187.4 6,930.5 54.72 SLEEVE 5.000 BAKER CMD SLIDING SLEEVE (C) w/ 3.813" 'BX' PROFILE BAKER CMD 3.813 9,299.1 6,990.7 60.30 PACKER 5.970 BAKER S-3 PACKER w/ MILLOUT EXTENSION BAKER S-3 3.875 9,404.6 7,039.4 63.83 NIPPLE 5.000 HES XN NIPPLE HES XN 3.725 9,415.6 7,044.2 64.06 WLEG 5.000 BAKER WIRELINE GUIDE 3.875 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 2,231.6 2,014.7 46.68 ISO-SLEEVE 4.5" ISO sleeve on 3.812" DB Lock Camco ISO 5/18/2023 2.250 4,160.0 3,371.7 44.81 PACKER - PATCH - UPR 4-1/2" Paragon II Packer, ME @ 4163' RKB. Paragon PIIP ALP 45011 5/17/2023 2.000 4,164.7 3,375.1 44.80 SPACER PIPE Spcer Pipe 5/17/2023 1.995 4,170.0 3,378.8 44.78 LEAK - TUBING Tubing leak 4,170' 5/15/2023 0.000 4,181.5 3,387.0 44.74 ANCHOR LATCH Anchor Latch Paragon PIIP ALPA L 45020 5/17/2023 2.000 4,182.0 3,387.4 44.74 PACKER - PATCH - LWR 4-1/2" Paragon II Packer, ME @ 4185' RKB, wilth lower WLEG, note standard 4.5 SDRT to retrieve Paragon PIIP ALPP 45008 5/15/2023 2.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 4,170.4 3,379.1 44.78 1 GAS LIFT OPEN BK-5 1 4/11/2023 Patch Over 7,422.7 5,696.4 44.37 2 GAS LIFT GLV BK-5 1 1,737.0 4/11/2023 0.188 9,073.6 6,861.5 51.07 3 GAS LIFT OV BK-5 1 0.0 4/10/2023 0.250 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 9,972.0 7,167.0 90.25 OPEN HOLE 6.125 6.125 CD2-45, 6/20/2023 2:09:44 PM Vertical schematic (actual) OPEN HOLE; 9,972.0-13,402.0 PRODUCTION; 34.5-9,972.0 PACKER; 9,299.0 GAS LIFT; 9,073.6 GAS LIFT; 7,422.7 PACKER - PATCH - LWR; 4,182.0 ANCHOR LATCH; 4,181.5 GAS LIFT; 4,170.4 SPACER PIPE; 4,164.7 LEAK - TUBING; 4,170.0 PACKER - PATCH - UPR; 4,160.0 SURFACE; 36.6-2,764.3 NIPPLE; 2,231.6 ISO-SLEEVE; 2,231.6 CONDUCTOR; 37.0-114.0 WNS PROD KB-Grd (ft) 44.10 RR Date 11/29/200 3 Other Elev CD2-45 ... TD Act Btm (ftKB) 13,402.0 Well Attributes Field Name ALPINE Wellbore API/UWI 501032039500 Wellbore Status PROD Max Angle & MD Incl (°) 92.96 MD (ftKB) 12,517.62 WELLNAME WELLBORECD2-45 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: WRDP ORIGINATED TRANSMITTAL DATE:6/24/2020 ALASKA E-LINE SERVICES TRANSMITTAL #:3093 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Alpine PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET #WELL #API #LOG DESCRIPTION DATE OF LOG 3093 CD2-45 50-103-20395-00 GR/CCL 6/16/2020 DELIVERED TO DIGITAL FILE PRINTS CD's Company & Address # of Copies # of Prints # of Copies BP North Slope 0 0 0 EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids 900 E. Benson Blbd. - Anchorage, AK 99508 Conoco Phillips Alaska Inc.1 0 0 Attn: NSK-69 700 G Street Anchorage, Alaska 99501 AOGCC 1 0 0 ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501-3539 DNR 1 0 0 Attn: Adam Manzer-Natural Resource Tech II DNR, Division of Oil & Gas 550 West 7th Ave, Suite #1100 - Anchorage, AK 99501 RECEIVED BY Print Name Signature Date Please return via e-mail a copy to both Alaska E-Line Services and Conoco Phillips Alaska: tom.osterkamp@conocophillips.com reception@ake-line.com Abby Bell Abby Bell 06/24/2020 Received by the AOGCC 06/24/2020 PTD: 2012120 E-Set: 33392 ORIGINATED TRANSMITTAL DATE:6/17/2020 ALASKA E-LINE SERVICES TRANSMITTAL #:3088 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Alpine PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET #WELL #API #LOG DESCRIPTION DATE OF LOG 3088 CD2-45 50-103-20395-00 GR/CCL 6/14/2020 DELIVERED TO DIGITAL FILE PRINTS CD's Company & Address # of Copies # of Prints # of Copies BP North Slope 0 0 0 EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids 900 E. Benson Blbd. - Anchorage, AK 99508 Conoco Phillips Alaska Inc.1 0 0 Attn: NSK-69 700 G Street Anchorage, Alaska 99501 AOGCC 1 0 0 ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501-3539 DNR 1 0 0 Attn: Adam Manzer-Natural Resource Tech II DNR, Division of Oil & Gas 550 West 7th Ave, Suite #1100 - Anchorage, AK 99501 RECEIVED BY Print Name Signature Date Please return via e-mail a copy to both Alaska E-Line Services and Conoco Phillips Alaska: tom.osterkamp@conocophillips.com reception@ake-line.com Received by the AOGCC 06/17/2020 PTD: 2012120 E-Set: 33381 Abby Bell Abby Bell 06/17/2020 • I WELL LOG TRANSMITTAL PROACTIVE DIAGNOSTIC SERVICES, INC. DATA LOGGED /R/2016 M.K.BENDER To: AOGCC Makana Bender 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 SUMMED KV 0 92016 Fax: (907) 245-8952 1) Caliper Report 24-Jul-16 CD2-45 1 Report /CD 50-103-20395-00 2_1-7 ro'S 2) Press/Temp Survey 24-Jul-16 CD2-45 Color Log / Report/CD 50-103-20395-00 2:1 4c Signed : Mett4g4usozDate : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE(q MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D.\Achives\MasterTemplateFi les\Templates\Distribution\TransmittalSheets\ConocoPhillips_Transmit.docx '1_0\-"2--k 2.. 1 • • 1_,,-7 443 1 IIII Memory Multi-Finger caliper cop Log Results Summary I Company: ConocoPhillips Alaska, Inc. Well: CD2-45 Log Date: July 24, 2016 Field: Alpine I Log No.: 15638 State: Alaska Run No.: 1 API No. 50-103-20395-00 Pipe Description: 4.5 inch 12.6 lb. L-80 IBTM Top Log Interval: Surface I Pipe Use: Tubing Bottom Log Interval: 9,416 Ft. (MD) Inspection Type : Corrosive & Mechanical damage Inspection U COMMENTS : This caliper data is tied into the WLEG at 9,416 feet(Driller's Depth). This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical Idamage. The caliper recordings indicate the 4.5 inch tubing appears to be in good to fair condition, with a maximum I recorded wall penetration of 31% in a line of corrosion in joint 95(4,208 ft). Recorded damage appears as isolated pitting, a line of pits, and line corrosion. No significant areas of cross-sectional wall loss are recorded. The caliper recordings indicate scale-like deposits from—8,800 feet to—9,070 feet, restricting the I.D. to 3.67 inches at 9,404 feet. No other significant I.D. restrictions are recorded. A graph illustrating the Iminimum recorded diameters on a joint-by-joint basis across the 4.5 inch tubing is included in this report. IMAXIMUM RECORDED WALL PENETRATIONS : J@Soil pt[J!`t Percent ellt 1)(til r) I iC'if211oP1 Isr,5 ( i.?=:rl I Line Corrosion 31 95 4,208 Ft. (MD) Line of Pits 29 81 3,564 Ft. (MD) Line of Pits 28 94 4,141 Ft. (MD) Line of Pits 27 98 4,318 Ft. (MD) IIsolated Pitting 26 131 5,789 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: I No significant areas of cross-sectional wall loss (>7%)are recorded. MAXIMUM RECORDED ID RESTRICTIONS : IDescrnphon Minimum Reco d d Diar eters ;,0I( r,i, Deposits 3.67 inches 73 3,197 Ft. (MD) Deposits 3.70 inches 205 9,058 Ft. (MD) IDeposits 3.71 inches 205.1 9,068 Ft. (MD) No other significant I.D. restrictions are recorded. II I B. Suhanek C. Waldrop M. Adams Field tangloeei(s) I ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford,TX 77497 Phone: (281)431-7100 or(888) 565-9085 Fax: (281)431-7125 E-mail: PDSAnalysis@amemorvlog.com Prudhoe Bay Field Office Phone: (907)659-2307 Fax: (907)659-2314 I • • u Correlation of Recorded Damage to Borehole Profile • Pipe 1 4.5 in (6.6'-941,5.6') Well: CD2-45 I Field: Alpine Company: ConocoPhillips Alaska,Inc. Country: USA Survey Date: July 24, 2016 I 1 ■ Approx.Tool Deviation . Approx.Borehole Profile I 1 — 10 I25 1,067 t50 _ 2,160 I 753,276 "11 .'-.4.' I GLM 1 100 4,388 E I c Z s cz '3 125 5,485 °' I — 150 6,577 I GLM2 A J 175 un 7,699 200 _ 8,798 I GLM 3 _ I I 211.3 9,416 0 50 100 Damage Profile(%wall)/Tool Deviation (degrees) IBottom of Survey=211.3 U • • IMinimum Diameter Profile (tRS., IWell: CD2-45 Survey Date: July 24,2016 Field: Alpine Tool Type: UW MFC 40 No.218452 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 inches I Country: USA Tubing I.D.: 3.958 inches IMinimum Measured Diameters (in.) 2.75 3 3.25 3.5 3.75 I 0.1 - 7 10 407 20 I 845 301 1,286 I 401, 1 1,726 I 50- 2,160 I 1 I57 1 2,487 67 2,926 1 I77 I 3,364 87- j 3,798 94.3 4,163 cu E 104 4,563 0 c I 114 5,002 c.' a. cu 124 5,441 p I 134-- 5,879 144 6,319 I 154 6,754 164 7,191 I 171 7,523 181 7,963 I 191 8,402 201 8,840 I 207.1 9,175 211.1 _ _ _ _ ��9,403 I • • IPDS Report Overview ,S Body Region Analysis Well: CD2-45 Survey Date: July 24,2016 Field: Alpine Tool Type: UW MFC 40 No.218452 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 inches I Country: USA No. of Fingers: 40 Pipe 4.5 in. 12.6 ppf L-80 IBTM Analyst: C.Waldrop Pipe Nom.OD Weight Grade&Thread Nom.ID Top Depth Bottom Depth 4.5 in. 12.6 ppf L-80 IBTM 3.958 in. 7 ft. 9,416 ft. IPenetration (%wall) Damage Profile(%wall) 200 Ion Penetration body la. Metal loss body 0 50 100 0.1 150 1 100 I 50 50( 1---: I0 0 to 20 to 40 to over 1 1._ I 20% 40% 85% 85% Number of joints analyzed(total=225) 171 54 0 0 GLM 1 (6:00) 96 - — 1 - Damage Configuration(body) I 100 i ■ 80 ■ r ■ 146 60 ■■ 40 GLM 2 (4:30) I 20 ■ ■■ 194 0 I Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos.Hole GLM 3 (10:00) Number of joints damaged(total= 126) I39 0 87 0 0 Bottom of Survey=211.3 I I • 0 I 1111 PDS Report Joint Tabulation Sheet I Well: CD2-45 Survey Date: July 24,2016 Field: Alpine Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. I Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 4.5 in. 12.6 ppf L$0 IBTM Tubing 3.958 in. 0.271 in. 7 ft. 9,416 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) ' (in.) (in.) % (in.) 0 50 100 0.1 7 0 0.01 4 1 3.92 Pup 1 10 0 0.04 14 3 3.90 I 2 58 0 0.04 13 3 3.89 Lt. Deposits. 3 102 0 0.04 16 4 3.91 Shallow Line of Pits. 4 146 0 0.04 13 3 3.91 5 190 0 0.03 13 3 3.90 ii 6 234 0 0.02 7 1 3.90 I7 275 0 0.04 14 3 3.90 8 319 0 0.04 16 5 3.91 Shallow Line of Pits. 9 363 0 0.04 15 4 3.89 Shallow Line of Pits.Lt. Deposits. 10 407 0 0.03 12 3 3.92 11 451 0 0.03 13 3 3.92 12 495 0 0.03 11 2 3.93 13 538 0 0.04 16 3 3,91 Shallow Line of Pits. 14 582 0 0.04 13 2 3.91 I 15 626 0 0.04 13 2 3.92 16 670 0 0.04 13 3 3.89 Lt. Deposits. 17 713 0 0.04 14 3 3.92 18 757 0 0.03 13 4 3.89 Lt. Deposits. I 19 801 0 0.04 14 3 3.87 Lt. Deposits. 20 845 0 0.04 14 2 3.93 21 889 0 0.05 17 3 3.89 Shallow Line Corrosion.Lt. Deposits. ■ 22 933 0 0.03 11 2 3.92 I 23 977 24 1021 0 0.04 14 3 3.91 0 0.04 14 3 3.91 25 1067 0 0.04 14 2 3.91 26 1111 0 0.04 15 3 3.90 Shallow Pitting. 27 1155 0 0.04 15 2 3.90 Shallow Line of Pits.Lt. Deposits. I28 1199 0 0.04 15 3 3.90 Shallow Line of Pits. 29 1243 0 0.05 18 4 3.88 Shallow Line Corrosion.Lt. Deposits. 30 1286 0 0.02 9 1 3.89 Lt. Deposits. 31 1331 0 0.04 14 3 3.89 Lt. Deposits. I 32 1375 0 0.04 14 2 3.89 Lt. Deposits. 33 1419 0 0.05 17 2 3.89 Shallow Line of Pits.Lt. Deposits. 34 1462 0 0.05 17 4 3.89 Shallow Line of Pits.Lt. Deposits. ■ 35 1507 0 0.05 17 3 3.91 Shallow Line of Pits. I 36 1550 0 0.05 18 4 3.86 Shallow Line Corrosion.Lt. Deposits. ■ 37 1593 0 0.04 16 3 3.85 Shallow Line Corrosion.Lt. Deposits. ■ 38 1637 0 0.06 21 3 3.90 Line of Pits. 39 1681 0 0.04 14 3 3.90 I 40 1726 0 0.04 13 2 3.85 Lt. Deposits. 41 1767 0 0.04 15 1 3.87 Shallow Pitting. Lt.Deposits. 42 181 1 0 0.04 15 2 3.87 Shallow Pitting. Lt.Deposits. 43 1855 0 0.04 16 3 3.86 Shallow Pitting. Lt.Deposits. I 44 1900 0.04 0.05 18 3 3.88 Shallow Line of Pits.Lt. Deposits. 45 1943 0.04 0.07 26 4 3.87 Line Corrosion. Lt.Deposits. 46 1987 0 0.05 17 2 3.84 Shallow Pitting. Lt.Deposits. 47 2031 0 0.07 24 3 3.89 Isolated Pitting. Lt.Deposits. 48 2075 0 0.07 24 3 3.89 Line of Pits. Lt.Deposits. I49 2119 0 0.07 24 4 3.89 Line of Pits. Lt.Deposits. IPenetration Body Metal Loss Body I Page 1 I III 1111 IPDS Report Joint Tabulation Sheet t-ii 10.E I Well: CD2-45 Survey Date: July 24,2016 Field: Alpine Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. I Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 4.5 in. 12.6 ppf L 80 I BTM Tubing 3.958 in. 0.271 in. 7 ft. 9,416 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) I (in.) (in.) % (in.) 0 50 100 50 2160 0.04 0.06 . 21 4 3.91 Line of Pits. 50.1 2204 0 0.05 17 3 3.85 Pup Shallow Pitting. Lt.Deposits. I 50.2 2214 0 0 0 0 3.79 4.5"Camco BALD SSSV Nipple 50.3 2219 0 0.03 13 2 3.91 Pup 51 2228 0 0.04 14 3 3.89 Lt. Deposits. ■ 52 2272 0 0.04 15 3 3.89 Shallow Pitting. Lt.Deposits. 53 2313 0 0.05 20 4 3.88 Isolated Pitting. Lt.Deposits. ■ I 54 2354 0 0.04 15 3 3.91 Shallow Pitting. ■ 55 2399 0 0.05 18 5 3.89 Shallow Pitting. Lt.Deposits. ■ 56 2443 0 0.05 18 4 3.89 Shallow Line of Pits.Lt. Deposits. ■ 57 2487 0 0.04 16 3 3.89 Shallow Line of Pits.Lt. Deposits. ■ ' 58 2530 0.05 0.05 . 17 3 3.87 Shallow Pitting. Lt.Deposits. ■ 59 2574 0 0.04 15 5 3.87 Shallow Pitting. Lt.Deposits. ■ 60 2618 0 0.06 22 4 3.89 Line of Pits. Lt.Deposits. 61 2661 0 0.05 19 3 3.88 Shallow Pitting. Lt.Deposits. I 62 2705 0 0.05 20 6 3.88 Isolated Pitting. Lt.Deposits. 63 2749 0 0.06 20 6 3.89 Line of Pits. Lt.Deposits. 64 2794 0 0.05 19 7 3.89 Shallow Pitting. Lt.Deposits. 1 65 2838 0 0.05 17 3 3.88 Shallow Line of Pits.Lt. Deposits. ■ I 66 2883 0 0.05 17 3 3.88 Shallow Line of Pits.Lt. Deposits. ■ 67 2926 0 0.05 20 6 3.84 Line of Pits. Lt.Deposits. 68 2970 0 0.04 15 4 3.88 Shallow Pitting. Lt.Deposits. 69 3014 0 0.04 16 5 3.88 Shallow Line of Pits.Lt. Deposits. I 70 3058 0 0.06 21 4 3.86 Line of Pits. Lt.Deposits. 71 3102 0 0.05 18 5 3.89 Shallow Pitting. Lt.Deposits. 72 3145 0 0.05 18 4 3.90 Shallow Line of Pits. 73 3188 0.05 0.06 23 6 3.67 Isolated Pitting. Deposits. 74 3232 0.06 0.06 24 3 3.88 Line of Pits. Lt.Deposits. ■ I 75 3276 0 0.07 25 4 3.88 Line of Pits. Lt.Deposits. 76 3320 0 0.06 22 3 3.89 Line of Pits. Lt.Deposits. ■ 77 3364 0.05 0.05 20 4 3.87 Isolated Pitting. Lt.Deposits. ■ 78 3408 0.05 0.06 20 4 3.88 Isolated Pitting. Lt.Deposits. I 79 3450 0 0.06 22 4 3.80 Isolated Pitting. Lt.Deposits. ■ 80 3494 0.05 0.06 24 4 3.88 Isolated Pitting. Lt.Deposits. 81 3538 0 0.08 29 4 3.88 Line of Pits. Lt.Deposits. 82 3581 0 0.07 26 6 3.82 Isolated Pitting. Lt.Deposits. I 83 3626 0.06 0.07 24 5 3.87 Line of Pits. Lt.Deposits. 84 3666 0.04 0.07 25 5 3.87 Line of Pits. Lt.Deposits. 85 3710 0 0.07 25 5 3.83 Line of Pits. Lt.Deposits. 86 3755 0.05 0.07 25 4 3.87 Line of Pits. Lt.Deposits. I 87 3798 0.06 0.06 23 5 3.86 Line of Pits. Lt.Deposits. 88 3841 0.06 0.05 20 6 3.86 Line of Pits. Lt.Deposits. 89 3886 0.05 0.06 23 6 3.86 Line of Pits. Lt.Deposits. 1 90 3929 0.06 0.06 24 4 3.88 Line of Pits. Lt.Deposits. I 91 3974 0 0.07 24 4 3.84 Line of Pits. Lt.Deposits. 92 4017 0.05 0.07 25 3 3.87 Line of Pits. Lt.Deposits. 93 4061 0 0.05 19 3 3.86 Shallow Line of Pits.Lt. Deposits. 94 4102 0.07 0.08 28 6 3.88 Line of Pits. Lt.Deposits. 94.1 4146 0 0.05 19 6 3.89 Pup Shallow Pitting. Lt.Deposits. ' 94.2 4156 0 0 0 0 3.86 GLM 1 (Latch @ 6:00) Penetration Body Metal Loss Body I Page 2 I • • I 11111 PDS Report Joint Tabulation Sheet I Well: CD2-45 Survey Date: July 24, 2016 Field: Alpine Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. I Pipe Description 4.5 in. 12.6 ppf L-80 IBTM Tubing Nom. ID Body Wall Top Depth Bottom Depth 3.958 in. 0.271 in. 7 ft. 9,416 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) I (in.) (in.) % (in.) 0 50 100 94.3 4163 0 0.05 17 2 3.90 Pup Shallow Pitting. 95 4173 0 0.08 31 5 3.86 Line Corrosion. Lt.Deposits. I 96 4217 0.06 0.07 25 6 3.91 Line of Pits. 97 4261 0 0.07 25 4 3.88 Line of Pits. Lt.Deposits. 98 4304 0.04 0.07 27 3 3.89 Line of Pits. Lt.Deposits. 99 4346 0 0.07 26 5 3.86 Line of Pits. Lt.Deposits. ■ 100 4388 0.05 0.06 23 3 3.86 Line of Pits. Lt.Deposits. I 101 4432 0.05 0.06 23 5 3.88 Line of Pits. Lt.Deposits. ■ 102 4476 0.05 0.07 26 3 3.89 Line of Pits. Lt.Deposits. 103 4520 0 0.05 17 3 3.85 Shallow Line of Pits.Lt. Deposits. ■ 104 4563 0.04 0.06 23 3 3.89 Line of Pits. Lt.Deposits. ■ I 105 4607 0 0.06 20 4 3.89 Line of Pits. Lt.Deposits. ■ 106 4651 0 0.06 24 3 3.89 Line of Pits. Lt.Deposits. ■ 107 4694 0 0.04 16 3 3.89 Shallow Line of Pits.Lt. Deposits. ■ 108 4738 0 0.05 19 4 3.90 Shallow Pitting. ■ I 109 4783 0 0.07 25 2 3.90 Line of Pits. ■ 110 4826 0 0.04 15 3 3.88 Shallow Line of Pits.Lt. Deposits. ■ 111 4870 0 0.04 13 2 3.90 112 4915 0 0.05 18 3 3.90 Shallow Line of Pits. ■ I 113 4959 0 0.07 25 3 3.90 Line of Pits. ■ 114 5002 0 0.06 21 3 3.88 Isolated Pitting. Lt.Deposits. ■ 115 5046 0 0.04 16 3 3.88 Shallow Line of Pits.Lt. Deposits. ■ 116 5091 0 0.04 15 3 3.88 Shallow Pitting. Lt.Deposits. ■ I 117 5134 0 0.07 25 3 3.88 Line of Pits. Lt.Deposits. el 5178 0 0.04 16 2 3.88 Shallow Pitting. Lt.Deposits. ■ 119 5223 0 0.04 13 4 3.90 ■ 120 5267 0 0.04 16 4 3.91 Shallow Pitting. ■ 121 531 1 0 0.05 20 4 3.89 Line of Pits. Lt.Deposits. ■ I 122 5355 0 0.04 14 3 3.90 ■ 123 5397 0 0.04 15 3 3.90 Shallow Line of Pits. ■ 124 5441 0 0.04 14 3 3.90 ■ 125 5485 0 0.05 17 3 3.91 Shallow Line of Pits. ■ I 126 5529 0 0.05 20 3 3.90 Line of Pits. ■ 127 5573 0 0.04 13 4 3.88 Lt. Deposits. • 128 5615 0 0.06 21 4 3.91 Isolated Pitting. ■ 129 5659 0 0.04 14 6 3.91 1 I 130 5702 0 0.03 13 5 3.90 ■ 131 5747 0 0.07 26 2 3.89 Isolated Pitting. Lt.Deposits. ■ 132 5791 0 0.04 14 5 3.88 Lt. Deposits. ■ 133 5835 0 0.03 11 3 3.89 Lt. Deposits. ■ I 134 5879 0 0.04 15 3 3.89 Shallow Pitting. Lt.Deposits. 135 5923 0 0.02 8 3 3.86 Lt. Deposits. 136 5967 0 0.06 21 4 3.89 Isolated Pitting. Lt.Deposits. a 137 6010 0 0.04 14 4 3.89 Lt. Deposits. I 138 6055 0 0.03 10 3 3.89 Lt. Deposits. 139 6099 0 0.03 12 1 3.89 Lt. Deposits. 140 6143 0 0.04 16 3 3.89 Shallow Line of Pits.Lt. Deposits. ■ 141 6186 0 0.03 13 4 3.91 ■ 142 6231 0 0.04 14 3 3.89 Lt. Deposits. I143 6275 0 0.03 10 2 3.88 Lt. Deposits. IPenetration Body Metal Loss Body I Page 3 I • • I PI PDS Report Joint Tabulation Sheet I Well: CD2-45 Survey Date: July 24, 2016 Field: Alpine Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc I Pipe Description 4.5 in. 12.6 ppf LSO I BTM Tubing Nom. ID Body Wall Top Depth Bottom Depth 3.958 in. 0.271 in. 7 ft. 9,416 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) I (in.) (in.) % (in.) 0 50 100 144 6319 0 0.05 18 2 3.89 Shallow Line of Pits.Lt. Deposits. 145 6363 0 0.03 10 3 3.88 Lt. Deposits. 146 640 7 0 0.03 12 4 3.92 ■ I 147 6451 0 0.03 11 3 3.90 ■ 148 6490 0 0.04 14 3 3.90 ■ 149 6533 0 0.04 15 4 3.82 Shallow Pitting. Lt.Deposits. ■ 150 6577 0 0.04 16 4 3.90 Shallow Line of Pits.Lt. Deposits. ■ I 151 6621 0.04 0.05 18 4 3.90 Shallow Pitting. Lt.Deposits. ■ 152 6665 0 0.03 10 3 3.88 Lt. Deposits. J 153 6709 0 0.04 13 3 3.86 Lt. Deposits. ■ 154 6754 0 0.05 17 2 3.85 Shallow Line Corrosion.Lt. Deposits. ■ I155 6797 0 0.05 17 4 3.88 Shallow Line of Pits.Lt. Deposits. •156 6841 0 0.03 10 1 3.91 • 157 6886 0 0.02 9 1 3.90 158 6929 0 0.05 18 4 3.91 Shallow Line Corrosion. ■ I 159 6973 160 7015 0 0.03 13 2 3.90 Lt. Deposits. 0 0.04 16 4 3.87 Shallow Line of Pits.Lt. Deposits. ■ 161 7059 0 0.04 15 4 3.90 Shallow Line Corrosion.Lt. Deposits. •■ 162 7102 0 0.04 15 4 3.88 Shallow Line of Pits.Lt. Deposits. ■ I 163 7147 0.04 0.05 18 3 3.86 Shallow Line Corrosion.Lt. Deposits. ■ 164 7191 0 0.03 12 4 3.83 Lt. Deposits. ■ 165 7235 0 0.03 11 2 3.85 Lt. Deposits. ■ 166 7277 0 0.04 16 3 3.91 Shallow Line Corrosion. 167 7320 0 0.03 10 3 , 3.88 Lt. Deposits. 168 7365 0 0.02 7 1 3.89 Lt. Deposits. 168.1 7409 0 0.02 7 2 3.87 Pup Lt. Deposits. 168.2 7417 0 0 0 0 3.85 GLM 2(Latch© 4:30) 168.3 7425 0 0.03 10 2 3.89 Pup Lt. Deposits. I169 7435 0 0.02 6 1 3.88 Lt. Deposits. 170 7479 0 0.03 10 3 3.91 171 7523 0 0.02 8 1 3.89 Lt. Deposits. 172 7567 0.04 0.05 18 3 3.90 Shallow Line Corrosion. I173 7611 174 7655 0 0.02 6 2 3.91 0 0.03 11 2 3.89 Lt. Deposits. ■ 175 7699 0 0.04 16 3 3.90 Shallow Line of Pits. 176 7743 0 0.02 7 2 3.86 Lt. Deposits. I 177 7787 0 0.02 7 2 3.88 Lt. Deposits. 178 7831 0 0.02 8 2 3.89 Lt. Deposits. 179 7875 0 0.04 14 3 3.90 ■ 180 7919 0 0.03 11 2 3.89 Lt. Deposits. I 181 7963 0 0.02 8 3 3.903 182 800 7 0 0.02 7 2 3.90 183 8051 0 0.04 14 2 3.89 Lt. Deposits. 184 8095 0 0.02 8 3 3.89 Lt. Deposits. 185 8138 0 0.05 17 3 3.88 Shallow Line of Pits.Lt. Deposits. I 186 8182 0 0.03 10 2 3.90 187 822 7 0 0.04 14 2 3.90 ■ 188 8270 0 0.04 14 1 3.88 Lt. Deposits. • 189 8314 0 0.04 15 3 3.88 Shallow Pitting. Lt.Deposits. ■ I 190 8358 0 0.04 15 2 3.86 Shallow Line of Pits.Lt. Deposits. Penetration Body Metal Loss Body I Page 4 I • I PDS Report Joint Tabulation Sheet I Well: CD2-45 Survey Date: July 24, 2016 Field: Alpine Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth I 4.5 in. 12.6 ppf L 80 IBTM Tubing 3.958 in. 0.271 in. 7 ft. 9,416 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) I (in.) (in.) % (in.) 0 50 100 191 8402 0 0.02 7 1 3.86 Lt. Deposits. 192 8446 0 0.04 14 3 3.85 Lt. Deposits. 193 8490 0 0.04 13 3 3.88 Lt. Deposits. I194 8534 0 0.04 14 3 3.87 Lt. Deposits. 195 8577 0 0.04 15 2 3.88 Shallow Line of Pits.Lt. Deposits. 196 8621 0 0.02 7 1 3.85 Lt. Deposits. 197 8665 0 0.04 14 2 3.87 Lt. Deposits. I 198 8710 0 0.02 7 1 3.86 Lt. Deposits. 199 8754 0 0.03 10 1 3.83 Lt. Deposits. • 200 8798 0 0.02 7 3 3.85 Lt. Deposits. C 201 8840 0 0.02 8 2 3.84 Lt. Deposits. I 202 8884 0 0.03 13 1 3.83 Lt. Deposits. 203 8928 0 0.01 4 0 3.83 Lt. Deposits. im 204 8972 0 0.01 2 0 3.79 Lt. Deposits. 205 9016 0 0 0 0 3.70 Deposits. I 205.1 9061 0 0 0 0 3.70 Pup Deposits. 205.2 9069 0 0 0 0 3.73 GLM 3(Latch @ 10:00) 205.3 9077 0 0.06 21 6 3.92 Pup Isolated Pitting. 206 9087 0 0.03 11 3 3.89 Lt. Deposits. 207 9131 0 0.04 15 2 3.90 Shallow Line of Pits. 207.1 9175 0 0.05 17 3 3.90 Pup Shallow Line Corrosion. 207.2 9184 0 0 0 0 3.75 4.5"Baker CMD Sliding Sleeve 207.3 9189 0 0.03 11 4 3.89 Pup Lt. Deposits. 208 9199 0 0.02 8 2 3.88 Lt. Deposits. 209 9244 0 0.04 13 3 3.88 Lt. Deposits. 209.1 9288 0 0.02 7 2 3.89 Pup Lt. Deposits. 209.2 9297 0 0 0 0 3.80 4.5"Baker S-3 Packer w/Millout Extension 209.3 9309 0 0.02 7 2 3.89 Pup Lt. Deposits. • I 210 9319 0 0.03 10 2 3.88 Lt. Deposits. is 211 9363 0 0.02 8 2 3.83 Lt. Deposits. ]s 211.1 9403 0 0 0 0 3.67 4.5"HES XN Nipple 211.2 9405 0.04 0.04 15 3 3.89 Pup Shallow Line of Pits.Lt. Deposits. I211.3 9416 0 0 0 0 3.82 4.5"WLEG IPenetration Body Metal Loss Body I I I I I Page 5 I • • IIIIII PDS Report Cross Sections CI* , IWell: CD2-45 Survey Date: July 24,2016 Field: Alpine Tool Type: UW MFC 40 No.218452 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 I Country: USA No. of Fingers: 40 Tubing: 4.5 in. 12.6 ppf L-80 IBTM Analyst: C.Waldrop I 1 Cross Section for Joint 95 at depth 4,208.059 ft. I Tool speed=50 Nominal ID=3.958 Nominal OD=4.5 Remaining wall area=97% ITool deviation=45° //. / I I I I I Finger=6 Penetration=0.083 in. Line Corrosion 0.08 in.=31%Wall Penetration HIGH SIDE=UP I I I I 1 • • r cik-rjits PDS Report Cross Sections IWell: CD2-45 Survey Date: July 24,2016 Field: Alpine Tool Type: UW MFC 40 No.218452 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 I Country: USA No. of Fingers: 40 Tubing: 4.5 in. 12.6 ppf L-80 IBTM Analyst: C.Waldrop I ICross Section for Joint 81 at depth 3,563.999 ft. I Tool speed=48 Nominal ID=3.958 Nominal OD=4.5 _ --------- Remaining wall area=99% j 111 Tool deviation=45° j I I 1 1 I Finger=6 Penetration=0.078 in. 1 Line of Pits 0.08 in.=29%Wall Penetration HIGH SIDE=UP I I I I ' • S PDS Report Cross Sections ' Well: CD2-45 Survey Date: July 24,2016 Field: Alpine Tool Type: UW MFC 40 No.218452 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 ' Country: USA No. of Fingers: 40 Tubing: 4.5 in. 12.6 ppf L-80 IBTM Analyst: C.Waldrop Cross Section for Joint 73 at depth 3,196.599 ft. ' Tool speed=48 Nominal ID=3.958 Nominal OD=4.5 Remaining wall area=99% ' Tool deviation=45° 1 I 1 I Minimum I.D.=3.667 in. Deposits Minimum Diameter=3.67 in. HIGH SIDE=UP I 1 ' • • kSoi PDS Report Cross Sections Well: CD2-45 Survey Date: July 24,2016 Field: Alpine Tool Type: UW MFC 40 No.218452 Company: ConocoPhillips Alaska,Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubing: 4.5 in. 12.6 ppf L-80 IBTM Analyst: C.Waldrop Cross Section for Joint 205 at depth 9,057.989 ft. ' Tool speed=49 Nominal ID=3.958 Nominal OD=4.5 Remaining wall area= 100% Tool deviation=50° I Minimum I.D.=3.701 in. Deposits Minimum Diameter=3.70 in. 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I I 014114.44.4,41-4.11,,.....-.......... I • Zol - Z1Z S WELL LOG TRANSMITTAL PROACTIVE DIAGNOSTIC SERVICES, INC. DATA LOGGED Ict 1201C. M. K.BENDER To: AOGCC RECEIVED Makana Bender 333 West 7th Avenue AU6.0 8 2016 Suite 100 Anchorage, Alaska 99501 AOGCC (907) 793-1225 VI RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 sCAPINED NOY p 92018 1) Caliper Report 24-Jul-16 CD2-45 1 Report /CD 50-103-20395-00 2'7 G'S 2) Press/Temp Survey 24-Jul-16 CD2-45 Color Log / Report/CD 50-103-20395-00 2� ,( Signed : 172,4412,41.#1.0%.,4/) Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\ConocoPhillips_Transmit.docx • • '2,01T 2, 12 z' �� oto e'c—- �C W � PROACTIVE UTACjNOSTiC SERVICES Static Survey Temperature / Pressure Chart Data CD2 _ 45 July 24th, 2016 • • 0 N N CO �QtotjSTS y 00eri — _ _ i: Li) u co 11 W M cd ai :,„ _ ._ Vi. 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L. o o a 'D toa ...6% o I- I E0 L4.1 o M v ic- c) Lo •V 03 i o 44oI I _ `l c� y V) II N - N y 1 . i 1 a - N - N \ _E N - - r o N 0 - s i I y - 0 o O 1 1 N a � � I (a 0 0 0 0 0 0 0 0 0 0 0 0 19 U O ` 0000000000000000000 0 0 0 0 0 0 0 0 0 0 0 0 O o0f�(Ou7�MN�OWaOhCO1f7Vc'7N� N N CZ N- Ul M N— 01 n L!7 Cl r ✓• %...i Q `•••1 Bea VISd i I STATE OF ALASKA • ALlikA OIL AND GAS CONSERVATION COMM ON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other:Scale Inhibitor Treatment CI 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development E Exploratory ❑ 201-212 3.Address: Stratigraphic❑ Service ❑ 6.API Number: P.O. Box 100360, Anchorage, AK 99510 50-103-20395-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 380075, 25559 CRU CD2-45 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): None Colville River Field/Alpine Oil Pool 11.Present Well Condition Summary: Total Depth measured 13402 feet Plugs measured None feet true vertical 7138 feet Junk measured None feet Effective Depth measured 13402 feet Packer measured 9299 feet true vertical 7138 feet true vertical 6991 feet ...., Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 16" 114' 114' Surface 2728' 9.625" 2764' 2382' SCANNED SEP 2 12016 Intermediate Production 9938' 7" 9972' 7167' RECEIVED��' Liner Perforation depth Measured Depth: Open Hole completion, 9972'- 13402' MAY 2 7 2016 True Vertical Depth: 7167'-7138' AOG CG Tubing(size,grade,measured and true vertical depth) 4.5", L-80, 9417' MD, 7045'TVD Packers and SSSV(type,measured and true vertical depth) Packer: Baker S-3 Packer w/Millout Extension, 9299' MD, 6991'TVD SSSV: WRDP-2, 2232' MD, 2015'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 9972'- 13402' MD Treatment descriptions including volumes used and final pressure: Please see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 513 732 1259 1141 212 Subsequent to operation: 504 373 1346 1356 207 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Developments Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil E Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ El SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Kerry Freedman Email Kerry.C.Freedman@cop.com Printed Name Kerry Freedman ,/ Title Principal Production Engineer Signature 711111;. {6 r• �Crry !/�4---✓ Phone 265-6579 Date 0.7A, '' 1/74. (////GI ie 64/A4 RBDMS Lt/ MAY 3 1 2016 Form 10-404 Revised 5/2015 Submit Original Only CD2-45 Scale Inhibition Treatment 5/13/16 Hybrid Scale Inhibitor Squeeze Job pumped 5/13/16 from 10:00 to 21:00 hrs. LRS= Little Red Services - Initial pressure TBG/IA/OA—618/1514/832 - LRS pumped 150 bbls Diesel/WAW5206/M209 preflush at 2 bpm,TBG/IA/OA- 160/1376/795 - LRS pumped 150 bbls Seawater/SCW3001 scale inhibitor main treatment at 2 bpm,TBG/IA/OA- 0/1330/784 - LRS pumped 1495 bbls Dead Crude/M209 overflush at 2—3 bpm,TBG/IA/OA—784/1378/869 Interval treated: 9,972'—13,402' MD ,: WNS PROD III CD2-45 ConocoPhillips Well Attributes Max Angle&MD TD A Wellbore API/OWl Field Name Wellbore Status pItial(°) MD(000) Act Elm(ft0B) r�I,iSKa.1nC. 501032039500 ALPINE PROD 1 92.96 12,517.62 13,402.0 r:wtun�hl8lnc --. Comment 112$(ppm) Date Annotation End Date KBGrd(ft) RIO Release Date CD2-45,5/1520161.1053 PM SSSV:WRDP Last WO: 44.10 116/2003 vertical schematic(actual) Annotation Depth MKS) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:GLV C/O,PILLED AND SET pproven 5/15/2016 WRDP HANGER:32.5 — Casing Strings Casing Description OD(In) ID(In) Top(600) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 14.688 37.0 114.0 114.0 109.00 H-40 WELD Casing Description OD(in) ID(In) Top(HKB) Set Depth(HKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread - 1.4 SURFACE 95/8 8.921 36.6 2,764.3 2,382.3 36.00 J-55 BTC lirrarl ' Casing Description 00(In) ID(In) Top(HKB) Set Depth(SKIN Set Depth(TV0)...WULen(I...Grade Top Thread PRODUCTION 7 6.276 34.5 9,972.0 7,167.0 26.00 L-80 BTCM Casing Description OD(In) ID(in) Top(HKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread I OPEN HOLE 61/8 6.125 9.972.0 13402.0 7,137.9 Tubing Strings i Tubing Desedpllon Slring Ma...ID(In) Top(HOE) Set Depth(k-.-Set Depth(TVD)(...Wt(lb Grade Top Connection IF TUBING 4112 3.958 32.5 9416.9 7,044-8 12.60 L-80 IBTM v Completion Details Nominal ID Top(ftKB) Top(TVD)(HKB) Top Incl(°) Item Des Com (In) CONDUCTOR 1370-114.0 32.5 32.5 0.00 HANGER FMC TUBING HANGER 4.500 2,231.6 2,014.7 46.68 NIPPLE CAMCO BAL-O NIPPLE 3.812 9,187.4 6,930.5 5472 SLEEVE BAKER CMD SLIDING SLEEVE w/3.813"'BX'PROFILE 3.813 NIPPLE;2,231.6 WRDP:2.231.8 I 9,299.1 6,990.7 60.30 PACKER BAKER 5-3 PACKER wl MILLOUT EXTENSION 3.875 9,404.6 7,039.4 63.83 NIPPLE HES XN NIPPLE 3.725 9,415.6 7,044.2 64.06 WLEG BAKER WIRELINE GUIDE 3.875 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top incl Top(MB) (MB) (°) Des Com Run Date ID(in) 2,231.6 2,014.7 46.68 WRDP 3.81"WRDP-2(S/N:HSS-130/3.82"PACKING/3 5/12/2016 2.250 SETS PACKING) Mandrel Inserts St ell SURFACE;36.6-2.764.3-✓4 on Top(TVD) Valve Latch Pon see TRO Run N Top(HKB) (RIM Make Model OD lin) Sere Type Type (In) (psi) Run Date Com 1 4,170.4 3,379.1 CAMCO KBG-2 1'GAS LIFT DMY BKS 0.000 0.0 6/27/2009 1 It 2 7,422.7 5,696.4 CAMCO KBG-2 1 GAS LIFT GLV BK-5 0.188 1,737.0 6/27/2009 3 9,073.6 6,861.5 CAMCO KBG-2 1 GAS LIFT OV BK-5 0.250 0.0 5/11/2016 GAS LIFT.4,170.4 Notes:General&Safety End Date Annotation 922010 NOTE:View Schematic w/Alaska Schemahc9.0 GAS LIFT,7,422.7 I GAS LIFT,9,073.6 H. ItSLEEVE.9,187.4 I E++ PACKER 9,259 0 NIPPLE,9,404 6 ! 6 III WLEG:9.415.5 PRODUCTION;34.5-9.972 0-- OPEN MOLE;9,972.0-13.402.0 STATE OF ALASKA ALAIIkA OIL AND GAS CONSERVATION COMOSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing fl Operations Shutdown fl Performed: Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program Rug for Redrill r Perforate New Pool r Repair Well fl Re-enter Susp Well r Other:Scale Inhibition Treatment 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory - 201-212 3.Address: 6.API Number: Stratigraphic r Service r P. 0. Box 100360,Anchorage,Alaska 99510 ' 50-103-20395-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 380075,25559 i CRU CD2-45 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Colville River Field/Alpine Oil Pool 11.Present Well Condition Summary: Total Depth measured • 13402 feet Plugs(measured) none true vertical • 7138 feet Junk(measured) none Effective Depth measured 13402 feet Packer(measured) 9299 true vertical 7138 feet (true vertical) 6991 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114 114 SURFACE 2728 9.625 2764 2382 PRODUCTION 9938 7 9972 7167 SCANNED JAN 1 12016 RECEIVED Perforation depth: Measured depth: open hole completion 9972'-13402' SEP 0 4 2015 True Vertical Depth: 7167'-7138' �� AOGGC Tubing(size,grade,MD,and ND) 4.5, L-80, 9417 MD,7045 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER S-3 PACKER W/MILLOUT EXTENSION @ 9299 MD and 6991 TVD NIPPLE-CAMCO BAL-O NIPPLE WITH WRDP INSTALLED @ 2232 MD and 2015 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 559 475 1337 1086 207 Subsequent to operation 391 271 1360 1067 211 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Fro Exploratory r- Development rF Service r Stratigraphic Copies of Logs and Surveys Run r 16.Well Status after work: ' Oil 17 Gas r WDSPL Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: none Contact Kerry Freedman Cad 265-6579 Email Kerry.C.Freedman(c�conocophillips.com Printed Name Kerry Freedman Title Principal Production Engineer Signature /,/ "/ Phone:265-6579 Date k� cel Zo1 5 ktL- Qui'I 1 RBDM SEp 0 8 2015 Form 10-404 Revised 5/2015 Submit Original Only • ! CD2-45 Scale Inhibition Treatment 8/7/15 Aqueous Scale Inhibitor Squeeze Job pumped 8/7/15 from 07:00 to 16:46. LRS= Little Red Services ACF=Alpine Central Facility - Initial pressure TBG/IA/OA—194/1076/800 - ACF pumped 30 bbls seawater for a tubing flush at 1.9 bpm,TBG/IA/OA-0/1226/800 - LRS pumped 12.5 bbls WAW5206 at .2 bpm while ACF pumped 113 bbls seawater at 3.1 bpm, TBG/IA/OA-0/1282/800 - LRS pumped 18.7 bbls SCW3001 scale inhibitor at .3 bpm while ACF pumped 107 bbls seawater at 3.1 bpm,TBG/IA/OA—0/1326/800 - ACF pumped 1,353 bbls seawater overflush at 3.1 bpm,TBG/IA/OA-0/1326/800 Interval treated: 9,972'—13,402' WNS CD2-45 ConocoPhillips Well Attributes s • Max Angle&MD TD AJB;Si7 Inc_ Wellbore API/DWI Field Name Wellbore Status Indy) MD(ftKB) Act Btm(ftKB) gam, 501032039500 ALPINE PROD 92.96 12,517.62 13,402.0 'w" Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date "' SSSV:WRDP Last WO: 44.10 1/6/2003 Well Co fn5 3/14/2013 6 20 30 AM Schemata Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag. Rev Reason:SET WRDP haggea 3/14/2013 Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd CONDUCTOR 16 14.688 37.0 114.0 114.0 109.00 H-40 WELD HANGER,32 N Casing Description String 0... String ID...Top(ftKB) Set Depth If...Set Depth(TVD)...String Wt..String...String Top Thrd r _ , SURFACE 95/8 8.921 36.6 2,764.3 2,382.3 36.00 J-55 BTC It Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd PRODUCTION 7 6.276 34.5 9,972.0 7,166.6 26.00 L-80 BTCM Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd OPEN HOLE 61/8 6125 9,972.0 13,402.0 7,137.9 Tubing Strings ii h( Tubing Description String 0... String ID...Top(kKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd TUBING 41/2 3.958 32.5 9,416.9 7,044.6 12.60 L-80 IBTM Completion Details Top Depth (TVD) Top Incl Noon... �'3 v.v a ?Top(ftKB) (ftKB) (°) Item Description Comment ID f n) 32.5 32.5 -0.36 HANGER FMC TUBING HANGER 4.500 CONDUCTOR, 2,231.6 2,014.7 46.68 NIPPLE CAMCO BAL-O NIPPLE 3.812 37-114 9,187.4 6,930.5 54.71 SLEEVE BAKER CMD SLIDING SLEEVE w/3.813"'BX'PROFILE 3.813 9,299.1 6,990.6 60.30 PACKER BAKER S-3 PACKER w/MILLOUT EXTENSION 3.875 NIPPLE,2,232 9,404.6 7,039.4 63.58 NIPPLE HES XN NIPPLE 3.725 WRDP,2,232 11419,415.6 7,044.0 64.28 WLEG BAKER WIRELINE GUIDE 3.875 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top Depth I d (TVD) Top Incl Top(ftKB) IftKB) (°) Description Comment Run Date ID(in) 2,231.6 2,014.7 46.68 WRDP DB LOCK ON WRDP(HSS-242BAL-0 OPERATED/3 3/7/2013 2.250 PACKING STACKS) iI Notes:General&Safety xEnd Date Annotation 9/2/2010 NOTE:View Schematic w/Alaska Schematic9.0 SU3764RFACE, , 1 fl GAS LIFT, 4,170 - �. li GAS OFT, a.3.3`-. 7.423 1IT . . i ,4, GAS LIFT, 9,074 W.-: r A SLEEVE,9,187 .Afka -- i PACKER,9.299I. NIPPLE,9,405 WLEG,9,416 II Mandrel Details Top Depth Top Port 5,,. (TVD) net OD Valve Latch Size TRO Run PRODUCTION, A k N...Top(ftKB) (ftKB) C) Make Model (in) Sery Type Type (in) (psi) Run Date Com... 34-9,972 OPEN HOLE, 1 4,170.4 3,378.4 43.94 CAMCO KBG-2 1 GAS LIFT DMY BK-5 0.000 0.0 6/27/2009 9,972-13,402 TD, 7D.13,aoz 2 7,422.7 5,695.8 43.66 CAMCO KBG-2 1 GAS LIFT GLV BK-5 0.188 1,737,0 6/27/2009 3 9,073.6 6,861.3 50.55 CAMCO KBG-2 1 GAS LIFT OV BK-5 0.313 0.0 6/27/2009 STATE OF ALASKA • AL4DA OIL AND GAS CONSERVATION COMOION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon Repair w ell r Rug Perforations [ Perforate j"" Other Scale Inhibition Alter Casing Rill Tubing Treatment g °" g Stimulate-Frac r Waiver Time Extension �" Change Approved Program rOperat. Shutdown Stimulate-Other r Re-enter Suspended Well 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. . Development j✓• Exploratory r 201-212 • 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-103-20395-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 380075,25559 CD2-45 ' 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Colville River Field/Alpine Oil Pool ' 11.Present Well Condition Summary: Total Depth measured 13402 ' feet Plugs(measured) none true vertical 7138 feet Junk(measured) none Effective Depth measured 13402 feet Packer(measured) 9299 true vertical 7138 feet (true vertical) 6991 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114 114 SURFACE 2728 9.625 2764 2382 PRODUCTION 9938 7 .g 9 2� ej r rr 3 7167 ED SCASS Perforation depth: Measured depth: open hole completion 9972-13402' True Vertical Depth: 7167'-7138' 5 it, Tubing(size,grade,MD,and TVD) 4.5, L-80,9417 MD,7045 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER S-3 PACKER W/MILLOUT EXTENSION @ 9299 MD and 6991 ND NIPPLE-CAMCO BAL-O NIPPLE @ 2231 MD and 2015 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): 9972'-13402' Treatment descriptions including volumes used and final pressure: see attached summary 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 463 1916 610 -- 224 Subsequent to operation 312 1718 695 -- 230 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development • Service r Stratigraphic r 16.Well Status after work: Oil Pi- Gas T WDSPL Daily Report of Well Operations XXX GSTOR r WIND r- WAG r GINJ r SUSP r SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: none Contact Cody Gauer an.263-4802 Email Cody.Gauer @conocophillips.com Printed Name Cod Gaue Title Sr. Production Engineer Signature Phone:263-4802 Date 7/3/z'3 1/L/ V M/13 RBDMS JUL - 820 Form 10-404 Revised 10/2012 �/� Submit Original Only • Scale Inhibition Treatment CD2-45 6/08/2013 Initial pressure TBG/IA/OA-700/1100/650; Facility pumped 50 bbls SW preflush; LRS pumped 3.2 bbls WAW5206(134 gal) at 0.4 bpm while facility pumped 30 bbls SW at 4 bpm, 150/1250/650; LRS pumped 33 bbls SCW3001WC(1373 gal)at 0.6 bpm while facility pumped 186 bbls of SW at 4 bpm, 0/1400/650; LRS pumped 3.2 bbls WAW5206(134 gal) at 0.4 bpm while facility pumped 30 bbls SW at 4 bpm, 0/1400/650;facility pumped 901 bbls of SW over-displacement. Final pressures:0/1400/650. Intervals treated: 9972'—13402' WNS CD2-45 • • ConocoPhillips 4 Well Attributes Max Angle&MD TD A3ask3II1C WellboreAPI/UWI Field Name Wellbore Status Inc!(1 MD(ftKB) Act Btu(ftKB) crape 501032039500 ALPINE PROD 9296 12,517.62 13,402.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date "' SSSV:WRDP Last WO: 44.10 1/6/2003 Well Donfie:-CD2-45,3/14/2013 620:30 AM Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:SET WRDP haggea 3/14/2013 Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd CONDUCTOR 16 14.688 37.0 114.0 114.0 109,00 H-40 WELD MANGER,32 mu x .,r pow Casing Description String 0... String ID...Top(ftKB) Set Depth(9...Set Depth(TVD)...String Wt...String...String Top Thrd SURFACE 9 5/8 8.921 36.6 2,764.3 2,382.3 36.00 J-55 BTC .j(: Casing Description String 0... String ID...Top(ftKB) Set Depth(9...Set Depth(TVD)...String Wt...String...String Top Thrd $`! PRODUCTION 7 6.276 34.5 9,972.0 7,166.6 26.00 L-80 BTCM Fp auri t' Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt..String...String Top Thrd OPEN HOLE 61/8 6.125 9,972.0 13,402.0 7,137.9 Tubing Strings ,' Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd h P TUBING 41/2 3.958 32.5 9,416.9 7,044.6 12.60 L-80 IBTM Completion Details t Top Depth (TVD) Top not Noon,.. Top(ftKB) (ftKB) (a) Item Description Comment ID(In) 32.5 32.5 -0.36 HANGER FMC TUBING HANGER 4.500 CONDUCTOR, 37-114 2,231.6 2,014.7 46.68 NIPPLE CAMCO BAL-O NIPPLE 3.812 9,187.4 6,930.5 54.71 SLEEVE BAKER CMD SLIDING SLEEVE w/3.813"'BX'PROFILE 3.813 9,299.1 6,990.6 60.30 PACKER BAKER S-3 PACKER w/MILLOUT EXTENSION 3.875 NIPPLE,2,232 9,404.6 7,039.4 63.58 NIPPLE HES XN NIPPLE 3.725 WRDP,2,232 e' 9,415.61 7,044.0 64.28 WLEG !BAKER WIRELINE GUIDE 3.875 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc,) Top Depth (TVD) Top Ind Top(ftKB) (ftKB) (°) Description Comment Run Date ID(In) 2,231.6 2,014.7 46.68 WRDP DB LOCK ON WRDP(HSS-242BAL-O OPERATED/3 3/7/2013 2.250 PACKING STACKS) Notes:General&Safety End Date Annotation -_ J 922010 NOTE:View Schematic w/Alaska Schematic9.0 SURFACE, '.1 37-2,764 J GAS LIFT, 4,170 T, I GAS LIFT, 7,423 HI I GAS LIFT, _t 9,074 _ —i I SLEEVE.9,187 PACKER,9299 - •x,5:M.,.s.,.s NIPPLE,9,405 WLEG,9,416 Mandrel Details Top Depth Top Port g„. (TVD) Incl OD Valve Latch Size TRO Run PRODUCTION, N...Top(ftKB) (ftKB) Ii Make Model (in) Sery Type Type (in) (psi) Run Date Com... 34-9,972 1 4,170.4 3,378.4 43.94 CAMCO KBG-2 1 GAS LIFT DMY BK-5 0.000 0.0 6/27/2009 OPEN HOLE, s.972-13,402 ® _ TD,13,402 2 7,422.7 5,695.8 43.66 CAMCO KBG-2 1 GAS LIFT GLV BK-5 0.188 1,737.0 6/27/2009 3 9,073.6 6,861.3 50.55 CAMCO KBG-2 1 GAS LIFT OV BK-5 0.313 0.0 6/27/2009 • STATE OF ALASKA • ~~~ ~ ~ ~~n ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS'~~~~~ ~"~ ~` gas ~~~'~• ~nmmissinrt 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ late ~ Other '.g ~~ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ S~V~ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ~r ConocoPhillips Alaska, InC. Development ~• Exploratory ^ 201-212 / [C~ 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20395-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 36', 53' AMSL CD2-45 « 8. Property Designation: 10. Field/Pool(s): ADL 380075, 25559 Colville River Field /Alpine Oil PooF 11. Present Well Condition Summary: Total Depth measured 13402' feet true vertical 7138' feet Plugs (measured) Effective Depth measured 13402' feet Junk (measured) true vertical 7138' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 114' 16" 114' 114' SURFACE 2728' 9-5/8" 2764' 2382' PRODUCTION 9936' 7" 9972' 7167' .. OPEN HOLE 3430' 5-1/2" 13402' 7138' Perforation depth: Measured depth: open hole completion fro m 9972'-13402' true vertical depth: 7167-7138' ~ ~~ ~ Ihi yy ~ J~ ~~ :'tl u5 ~~ t ~'- ~ 8yy~~ ,~ Tubing (size, grade, and measured depth) 4.5", L-80, 9417' MD. Packers & SSSV (type & measured depth) Baker S-3 pkr ~ 929s' Camco Bal-O nipple @ 2232' 12. Stimulation or cement squeeze summary: Intervals treated (measured) pumped 106 bbls scale squeeze Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 686 1583 189 -- 248 Subsequent to operation 406 ~ 1513 234 -- 243 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ • Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oi10 « Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none contact Tim Schneider @ 265-6859 Printed Name Tim Schneider Title Alpine Staff Engineer « Signature , Phone: 265-6859 Date ~ " ~ 6 T ~ P ared b h n Allsu Drake 263-4612 ~~~-JIJN ' ~l~~~roi`~ ~( Form 10-404 Revised 04/2006 ~ ~ .~ ~ Submit Original Only ~ ~~1~7' ~onocePhiliips Alusi~;.IT7C- "- WNS I ',We1lAtti f ' Wellbore AP / 501032 - Comment ' CONDUCTOR,_ 114 NIPPLE, 2,232 VALVE, 2.232 y SURFACE, 2,764 GAS LIFT, a i 70 GAS LIFT, _- 7.422 GAS LIFT. 9,073 SLEEVE, 9.187 - PACKER. 9.299 NIPPLE, 5406 WLEG, 9.416 -- --- TTL, 9.417--- -- PRODUCTION. 9,972 U _ OPEN FIOLE, ~ 13.402 TD, 13.402 - PRODUCTION • Status '.Inclination (° BAKtR S-3 PACKER W/MILL OUT 7, .TA 2 __...._. LE _. ...__ CD2-45 KR) Total Depth (HKB) ?,517.62 13 402 0 tl (H) Rig Release Data na.1a vsaoo3 s/2srzooa 8/12/2008 8/12/2008 8/12/2008 1/5/2003 WSR -Well Service Report Page 1 of 1 Well Service Report Wets Job Scope CPAI Rep CD2-45 Scale Inhibition Shirtliffe, Ryan Date Daily ~Vork Unit Number 4/25/2009 32 Initial & T!I/A Initia1300/900/650 Final Final - 0/750/625 Pressures: Field: ALPINE Pumped a aqueous SI squeeze into well with a total of 106.2 bbls of SW at 2.4 2`l 1ir' Summary b m 500 si .Job um ed as Tanned. O erations um ed the flush utilizin the p p g p p p p p p g manifold. STA:RTTIME O:PERAT.IOV 02:00 PM Rig in and p-test lines. 02:45 PM Pump 11 bbls SW+ 5206 at 2.4 bpm and 500 psi followed by 78.3 bbls SW+3001 at 2.4bpm, 500 psi. Pump a post flush Volume of 16.9 bbls at 2.4 bpm. 03:30 PM Rig out eq uipment. Operations to overflush weii with SW from manifold. Fluid Type To Well From Well Non- recoverable Note SEAWATER, WAW- 28 5206 SEAWATER, SCW- 78 3001 WC http://akapps.conocophillips.net/alaskawelleventquery/worklog.aspx?ID=6DD 1618... 5/28/2009 . . ConocdJ'hillips Alaska i~j¡ .ú}? )'; 'J 2:.0 ! P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ;.$fl Sf ,j §Gt ~e~~: tMiiie~ :i¡1ii'i\~&.1DJ~ ð\iT!!.mJT!~ March 24, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ............. . .-,,- M I - d-.~ 'J- - Dear Mr. Maunder: SCANNED Mb.R 2 B 2.007 Enclosed please find a spreadsheet with a list of wells from the: Alpine.fteld (ALP). Some of these wells were found to have a void in th~ c9.¢uctor.b;' 'SurfàÈê ëãSrng annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void respectively was coated with a corrosion inhibiter, RG2401 engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on March 21st, 2007. Schlumberger Well Services mixed 15.7 ppg Arctic set I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor sealant was pumped in a similar manner March 21 st - 22n , 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, \]}# Ä Arend' ConocoPhillips Well Integrity Field Supervisor ~ Attachment . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Alpine Field March 24,2001 Initial top of Well Name pro # cement ft Final top of Cement top off cement date ft Corrosion RG casing filler inhibitorl sealant vol. date al . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Alpine Field March 24,2001 Initial top of Well Name PTO # cement ft Final top of Cement top off cement date ft Corrosion RG casing filler inhibitorl sealant vol. date al . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marker.doc ) ) OC1 2 6 2005 To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Howard Okland 333 West 7tlt Avenue, Suite 100 Anchorage, Alaska 99501-3539 r!\rì,í"i'r\i¡j\li:iJ!~\;::; December (7':'2'003' 'c ij¡1I:n~,ž:~)i~ n WELL LOG TRANSMITTAL RE: MWD Formation Evaluation Logs: CD2-45, AK-MW-22201 CD2-45: Digital Log Images: 50-103-20395-00 / -:::;; J 3!;; if 7 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ~CANNED NOV 0 2 2005 Date: ) PJrv ;to 0 ~ tJ- (j)jJ Signed: Ì\ùJ -~I ~ ~ hi.; .zlM)~ DATA SUBMITTAL COMPLIANCE REPORT 2/1/2005 Permit to Drill 2012120 Well Name/No. COLVILLE RIV UNIT CD2-45 Operator CONOCOPHILLlPS ALASKA INC (¡-wi t 3 Nóv ,zó ¡j ( AP\ No. 50-103-20395-00-00 MD 13402 ..,/ TVD 7138 Completion Date 1/6/2003 /~ Completion Status 1-01L --- ----- ----- -- -------~ ------ REQUIRED INFORMATION Mud Log No Samples No - ----------- . ---~- - -------~----- DATA INFORMATION Types Electric or Other Logs Run: GRlRes/NewtlDensity Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Type Med/Frmt Number Name Scale Media No (ED~C_~ Directional Survey 1 Rpt Directional Survey ED ~D· [11685 I IS Vorifieatiofl ~ j"1 ~(,~ I ({e.S 4 Rpt LIS Verification 4 Rpt Directional Survey ;~-~ Directional Survey ~ V\ à.u.c../ r\ ~ ~ ED ,,--6 v(1685 klS Vcrifil..stioll . .-_~pt_ LI$ V~liCil.àtion~- I h:D C Pdf (12421 Rate of Penetration 25 1-4 (' \ : \ ED C Pdf 12421 Induction/Resistivity 25 1-4 I L/ /'ED C Lis 12421 Rate of Penetration 1-4 (ED C Lis 12421 I nd uction/Resistivity 1-4 .,/ - - - ------- Well Cores/Samples Information: Name Interval Start Stop Received Sent Current Status 1-01L UIC N Directional Survey No (data taken from Logs Portion of Master Well Data Maint) ~. Interval OH/ Start Stop CH Received Comments 0 13402 Open 1/15/2003 0 13402 Open 1/15/2003 2734 13337 Open 7/24/2003 REPLACES DATA RCVD i 04/17/2003 2734 13337 Open 7/24/2003 REPLACES DATA RCVD 04/17/2003 0 13402 Open 1/15/2003 MWD 0 13402 Open 1/15/2003 MWD 2734 13337 Open 4/17/2003 REPLACED BY NEW p!. t. _ 't. ¿ DATA RCVD 07/24/2003 If! '1 . 2734 13337 Open 4/17/2003 REPLACED BY NEW r)~5 ~~-~ \;(1 2774 13402 Open 2/26/2004 DATA RCVD 07/24/2003 ! Rap, DGR, EWR- Horizontal Presentation - -- MWD 2774 13402 Open 2/26/2004 Rap, DGR, EWR- Horizontal Presentation - MWD 2774 13402 Open 2/26/2004 Rap, DGR, EWR- Horizontal Presentation - MWD 2774 13402 Open 2/26/2004 Rap, DGR, EWR - Horizontal Presentation - MWD Sample Set Number Comments Permit to Drill 2012120 MD 13402 TVD 7138 ADDITIONAL INFORMATION Well Cored? Y ® Chips Received? ,~ Analysis Received? ~ ----- ---------- ---- - ~-----_. - Comments: --- -------------- --- -- -- -- ---- Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 2/1/2005 Well Name/No. COLVILLE RIV UNIT CD2-45 Opèrator CÓNOCOPHILLlPS ALASKA INC Completion Date 1/6/2003 Completion Status 1-01L Current Status 1-01L Daily History Received? &)IN <§/N Formation Tops J--c Date: API No. 50-103-20395-00-00 UIC N '-' c¡ ~ ~r- '---- ') ) I &0/ '-¿) I ~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 December 17, 2003 RE: MWD Fonnation Evaluation Logs: CD2-45, AK-MW-22201 CD2-45: Digital Log Images: 50-103-20395-00 1 CD Rom ) (}J../d l PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION' OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: Sign~~~~ ,~~~ ~ RECEIVED F- r-:-r-'. ? 6 ?OO¿1 _....1 '- '-" } ,~aska on & Gas Cons. Commiainn PJ~d1orage K~b\'i\ \ ~ ,} ) ?.p I - ~ 2- 1 , Co s? WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 June 04, 2003 RE:MWDFormation Evaluation Logs - CD2-45, AK-MW-22201 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AI< 99518 1 LDWG formatted Disc with verification listing. API#: 50-103-20395-00. f',.""~ ~~~=C'1~ 1(f""'" ¡ \J1l[,'~, ''''',' f'",,-,_, ~> !,:ij\I~, !~ W iT ~_. ~ ')1 ~ ""''''.. ~ t_ ¡¡, 1i_"IL"d7 Note: This Data Replaces Any Previous Data For Well CD2-45. JU~ L~ /;)(,;7 J' ...",1 ;) A!a~kt1 Or; ð '¿;2'''~ i ',1""; '. . ~," "v... CI:.:.,', r:Jn ,. ¡r:h1;1r*':''''~~ .... ~'v""'" \ , ) ; (lor-é)ld ) IIo?Ô WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7tlt Avenue, Suite 100 Anchorage, Alaska 99501-3539 April 11, 2003 RE: MWD Formation Evaluation Logs .- CD2-45, AK-MW-22201 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-103-20395-00. ~;,k t h.,'dl, ~~(\Ir~t~. \~ ~. ;-:i\/~;'f) ~ ~' .. ~},~~~ ~ "~~~,~ £.~-'~. 1.t;,l~'l R ¡¡ ., ,'¡' .",,~ ~ ,'$ ,I",,'" .<. :!.'...":1"1,' :t1'i .'..,' t\P~), -'l -r :~ ",':: , '." ... ," ' ,.~:::~",!,}':: ¡···\lr\~~~·..~:~~, \..~~" .:.. " t ~':~ ;.~""'. ,j~ ~," - . ) ) G. C. Alvord Alpine Drilling Team Leader Drilling & Wells ConocJP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 April 15, 2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for CD2-45 (APD 201-212/301-330/302-384) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the Alpine well CD2-45. If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, Ä.·( ()Z G. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells GCA/skad RECEIVED APR 1 6 2003 Alaska Oil & Gas Cons. Commission Anchorage O~l G.NAL ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Oil 0 Gas D 2. Name of Operator Conoco Phillips Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface Suspended D Abandoned D Service D r '"""_'-""~;':~:~~'~:;~,:, 1l0CA I ti..JN$'ìii; I.',' V~faf',l.m..... .':;:;.'~:, '.;'.;.'.'. IS\i1~"..\'tfi 't, ~, ',_ ' '" '~:"'~~'?' ~ {~.~'!!. ¥.. ,::<:<:!\ . .(.':'t~~~~·~"'''·~iI1 . [T,J!! ~ . '!~D3~ I.,...,....,---J :.-.>,:~: _-~1J ...:l1£-. \ , .........,'!o:''''',''''I~.'.....'i1':"T.'i ' (ASP: 371728,5974344) 2013'FNL,1509'FEL,Sec.2,T11N,R4E,UM At Top Producing Interval 829' FSL, 1291' FEL, Sec. 1, T11 N, R4E, UM At Total Depth 2466' FNL, 566' FWL, Sec. 7, T11 N, R5E, UM (ASP: 378988, 5968490) 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKB 36' & 52.7' AMSL ADL 380075 & 25559 12. Date Spudded 13. Date T.D. Reached /' 14. Date Comp., Susp. Or Aband. November 13, 2001 January 3, 2003 January 6, 2003 17. Total Depth (MD + TV D) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 13402' MD 17138' TVD 13402' MD 1 7138' TVD YES 0 No D (ASP: 377185, 5971815) Classification of Service Well 7. Permit Number 201-212/301-330/302-384 8. API Number 50-103-20395-00 9. Unit or Lease Name Colville River Unit 10. Well Number CD2-45 11. Field and Pool Colville River Field Alpine Oil Pool 15. Water Depth, if offshore NI A feet MSL 20. Depth where SSSV set 2231' MD 22. Type Electric or Other Logs Run G R/Res/NeuVDensity 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 114' Surface 2764' Surface 9972' CASING SIZE WT. PER FT. 16" 62.5# 9.625" 36# 7" 26# GRADE H-40 J-55 L-80 HOLE SIZE 16. No. of Completions 1 21. Thickness of Permafrost 1629' MD 42" CEMENTING RECORD 270 cf AS 1 AMOUNT PULLED 389 sx AS III Lite, 237 sx Class G 165 sx Class G 12.25" 8.5" 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) 4.5" TUBING RECORD DEPTH SET (MD) 9417' PACKER SET (MD) 9299' 25. SIZE open hole completion from 9972' - 13402' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) February 24, 2003 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF W A TER-BBL 2/28/2003 6.5 hours Test Period> 1085 703 0 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL press. 544 psi 416 psi 24-Hour Rate> 3651 3105 0 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. CHOKE SIZE GAS-OIL RATIO 850 56% OIL GRAVITY - API (corr) not available RECEIVED APR 1 6 2003 A'aska Oil & Gas Cons. Commission ^ntl1or~e N/A Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ORiG NAL Submit in duplicate IRBDMS fdrL GF APt< cJ¡ U ,n,\ u} 29. ) 30. ) GEOLOGIC MARKERS FORMATION TESTS NAME MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. CD2-45 Seabee Form. Nanushuk Gamma Ray Shale Kalubik Kuparuk Form. Miluveach Top Alpine D Top Alpine C Alpine A Base Alpine Base Alpine Inverted Base Alpine Base Alpine Inverted 2790' 4817.5' 8860' 9146.5' 9214' 9300' 9548.5' 9613' not present 11220' 11302' 12013' 12532' 2400' 3837' 6716' 6906' 6946' 7097' 7118' not present RECEIVED APR 1 6 2003 0'\ & Gas Cons. Commission A\aska , Anchorage 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Vern Johnson 265-6081 Signed /4" <- tJÞ( Chip Alvord Title Alpine Drilling Team Leader Date 4-1,s' (OJ Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct vyell completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ORIGINAL ) ) COrlocoPhillipsAlaska Pagel 015 Q.peråtions Summary Report 1.00 CEMENT DISP SURFAC Displace cement wI rig pumps wI 9.6 ppg mud @ 7.5 bbls/min slowed pumps wI 20 bbls displacement remaining to 4 bblsl min. Bumped plug wI 186.5 bbls - pressure to 1200 psi - release pressure - floats held - CI P @ 0515 hrs - full returns wI 100 bbls cement returns to surface 2.00 CEMENT PULD SURFAC RD cement head - LD landing joint - Flush & drain stack 2.50 DRILL RIRD INTRM1 ND diverter - attempt to pull starting spool & 20" Hydril- Unable to lift- Flush 20" Hydril & starting head - Observed junk wedged between hanger & landing ring 5.00 DRILL RIRD INTRM1 RU 350 ton elevators - MU landing joint - Pick up on 95/8" casing 8" - Observed junk fall out between 16" x 9 5/8" annulus - slack off on casing - LD landing joint - Remove 20" Hydril - Observed mandrel hanger not landed in landing ring - 4" high - Conferred with Drilling Team Leader in Anchorage - PU landing joint - PU on 9 5/8" casing & set emergency slips to stabilaze casing - casing set 6" high - LD landing Legal Well Name: CD2-45 Common Well Name: CD2-45 Event Name: ROT - DRILLING Contractor Name: doyon1 @ppco.com Rig Name: Doyon 19 Date From - To Hours Code Sub Phase Code 11/12/2001 12:00 - 18:00 6.00 MOVE MOVE MOVE 18:00-21:30 3.50 DRILL RIRD SURFAC 21 :30 - 22:00 0.50 DRILL OTHR SURFAC 22:00 - 22:30 0.50 DRILL OTHR SURFAC 22:30 - 00:00 1.50 DRILL PULD SURFAC 11/13/2001 00:00 - 01 :00 1.00 DRILL PULD SURFAC 01 :00 - 02:00 1.00 DRILL OTHR SURFAC 02:00 - 02:30 0.50 DRILL OTHR SURFAC 02:30 - 12:00 9.50 DRILL DRLG SURFAC 12:00 - 00:00 12.00 DRILL DRLG SURFAC 11/14/2001 00:00 - 05:00 5.00 DRILL DRLG SURFAC 05:00 - 06:30 1.50 DRILL CIRC SURFAC 06:30 - 08:30 2.00 DRILL WIPR SURFAC 08:30 - 10:00 1.50 DRILL CIRC SURFAC 10:00 - 12:30 2.50 DRILL TRIP SURFAC 12:30 - 16:00 3.50 DRILL PULD SURFAC 16:00 - 18:00 2.00 CASE RURD SURFAC 18:00 - 21 :00 3.00 CASE RUNC SURFAC 21 :00 - 21 :30 0.50 CASE CIRC SURFAC 21 :30 - 00:00 2.50 CASE RUNC SURFAC 11/15/2001 00:00 - 00:30 0.50 CASE RUNC SURFAC 00:30 - 01 :00 0.50 CEMENT PULD SURFAC 01 :00 - 03:00 2.00 CEMENTCIRC SURFAC 03:00 - 04:30 1.50 CEMENT PUMP SURFAC 04:30 - 05:30 05:30 - 07:30 07:30 - 10:00 10:00 - 15:00 Spud Date: 11/13/2001 End: Group: Start: 11/10/2001 Rig Release: 11/29/2001 Rig Number: 19 Description of Operations Move rig fl CD2 47 to CD2-45 - Accept rig @ 1800 hrs. 11/12/2001 NU 20" Hydril & diverter system - take on spud mud Pre spud meeting wI rig crew Function test diverter system - held shallow gas kick drill - Jeff Jones AOGCC waived witnessing of test PU & MU BHA # 1 MU BHA#1 RIH TO 80' - C/O ice & cmt fl 80' to 114' Pressure test stand pipe - kelly hose - mud line to 3500 psi Spud in @ 0230 hrs. - Drill 12 1/4" hole fl 114' to 1078' - 1063' TVD ADT 7.6 AST 4.5 ART 3.1 Drill 12 1/4" hole fl 1078' to 2450' - 2155' TVD ADT - 8.4 Drill 12 1/4" hole fl 2450' to 2774' TMD - 2389' TVD ADT 4.9 AST.2 ART 4.7 Circulate hole clean for wiper trip Wiper trip fl 2774' to 1554' - hole in good condition - RIH to 2774' Pump hi vis sweep & circulate hole clean for casing POOH to to run casing - stand back HWDP & Jars Lay Down - 8" monels, stabs, xo's, pony collar, MWD, motor, & bit Clean up rig floor Rig up to run 9 5/8" casing - Held pre-job safety meeting Ran 28 jts. 9 5/8" 36# J-55 BTC casing to 1186' - worked pipe through tight hole fl 1099' to 1186' Circulate bottums up fl 1186' Continue RIH w/9 5/8" 36# J-55 BTC casing to 2725' ( 64 jts. total ran in hole) MU landing joint - Land casing in wellhead on mandrel hanger wI shoe @ 2764' FC @ 2677' RD casing equipment & RU cement head Circulate & condition mud for cement job - recip. pipe PJSM - Cement 9 5/8" casing - pumped 40 bbls Biozan water wlnut plug as marker - pump 5 bbls water fl Dowell- Test lines to 2500 psi - Drop bottom plug - Pump 50 bbls ARCO spacer @ 10.5 ppg - Mix and pump 308 bbls lead slurry @ 10.7 ppg - observed nut plug @ sharkers - Switch to tail cement - Pumped 48 bbls tail slurry @ 15.8 ppg - drop top plug wI 20 bbls water fl Dowell Printed: 3/4/2003 11 :24:55 AM .) ) ConocoPhillips Alaska .Operati()ns Sumrnary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/15/2001 11/16/2001 11/17/2001 11/18/2001 11/19/2001 11/20/2001 CD2-45 CD2-45 ROT - DRILLING doyon1 @ppco.com Doyon 19 Sub From- To Hours Code Code. Phase 10:00 - 15:00 15:00 - 16:30 16:30 - 18:30 18:30 - 23:00 5.00 DRILL RIRD INTRM1 1.50 DRILL RIRD INTRM1 2.00 WELCTL NUND INTRM1 4.50 WELCTL BOPE INTRM1 23:00 - 00:00 1.00 WELCTL NUND INTRM1 00:00 - 03:00 3.00 DRILL PULD INTRM1 03:00 - 05:00 2.00 DRILL TRIP INTRM1 05:00 - 06:00 1.00 DRILL REAM INTRM1 06:00 - 07:00 1.00 DRILL OTHR INTRM1 07:00 - 08:30 1.50 RIGMNT RURD INTRM1 08:30 - 10:00 1.50 CEMENT DSHO INTRM1 10:00 - 10:30 0.50 DRILL CIRC INTRM1 10:30 - 11 :30 1.00 DRILL FIT INTRM1 11 :30 - 12:00 0.50 DRILL CIRC INTRM1 12:00 - 00:00 12.00 DRILL DRLG INTRM1 00:00 - 13:00 13.00 DRILL DRLG INTRM1 13:00 - 14:00 1.00 DRILL CIRC INTRM1 14:00 - 16:00 2.00 DRILL WIPR INTRM1 16:00 - 17:30 1.50 RIGMNT RURD INTRM1 17:30 - 19:00 1.50 DRILL TRIP INTRM1 19:00 - 19:30 0.50 DRILL REAM INTRM1 19:30 - 00:00 4.50 DRILL DRLG INTRM1 Spud Date: 11/13/2001 End: Group: Start: 11/10/2001 Rig Release: 11/29/2001 Rig Number: 19 Description of Operations joint Install FMC Unihaed & test metal to metal seal to 1000 psi Nipple up BOPE Set test plug - Test BOPE - pipe rams,blind rams, choke & kill line valves, choke manifold valves, floor safety & dart valves, top drive IBOP valves to 250 psi & 5000 psi - Hydril to 250 psi & 3500 psi - Perform Accumlator closure test - test witnessed & approved by Chuck Scheve AOGCC RD test equipment - blow down lines - pull test plug - set wear bushing MU BHA #2 - 8 1/2" RIH ( pick up 45 jts. 4" drill pipe f/ shed) to 2600' Break circ @ 2600' - wash down & tag cmt @ 2675' - Circ for casing test Rig up test casing to 2500 psi for 30 mins. - rig down Slip & cut 120' drill line - service top drive C/O cmt, top & btm plugs, drill FC, cmt, drill out shoe, & C/O rat hole to 2774' - Drill 20' new hole to 2794 Circulate hole clean for FIT Rig up - perform F.I.T. to 16.0 ppg EMW - rig down equip Change over to 9.4 ppg LSND mud Drill 8 1/2" hole f/ 2794' to 4040' - 3289' TVD ADT 7.1 ART 6.9 AST .2 Drill 8 1/2" hole f/ 4040' to 5281' 4150' TVD ADT 8.6 ART 8.3 AST .3 Pump sweep & circulate hole clean for wiper trip - flow check (static) - blow down top drive Wiper trip f/ 5281' to 2705' (27 stds) - hole in good condition - flow check (static) PJSM - slip & cut 90' drilling line - service top drive RIH f/ 2704' to 5190' - fill pipe every 2000' Establish circulation - Safety wash & ream f/ 5190' to 5281' Drill 8 1/2" hole f/ 5281' to 5663' 4439' TVD ADT 3.5 ART 2.0 AST .6 24 hr total - ADT 11.2 ART 10.3 AST.9 00:00 - 00:00 24.00 DRILL DRLG INTRM1 Drill 8 1/2" hole f/ 5663' to 7764' 5937' TVD ADT 14.4 ART 12.3 AST 2.1 00:00 - 12:30 12.50 DRILL DRLG INTRM1 Drill 8 1/2" hole f/ 7764' to 8719' - 6613' TVD ADT 7.7 ART 5.8 AST 1.9 12:30 - 13:30 1.00 DRILL CIRC INTRM1 Pump sweep & circulate hole clean for wiper trip - monitor well (static) 13:30 - 16:00 2.50 DRILL WIPR INTRM1 Wiper trip f/ 8719' to 5270' - hole in good condition - Monitor well (static) - Held kick drill 16:00 - 17:30 1.50 DRILL TRIP I NTRM 1 RIH f/ 5270' to 8628' 17:30 - 18:00 0.50 DRILL REAM INTRM1 Establish circulation - safety wash & ream f/ 8628' to 8719' - pump sweep 18:00 - 00:00 6.00 DRILL DRLG INTRM1 Drill 8 1/2" hole f/ 8719' to 9005' (began build & turn section) 6818' TVD ADT 4.1 ART 1.1 AST 3 00:00 - 12:00 12.00 DRILL DRLG INTRM1 Drill 8 1/2" hole f/ 9005' to 9500' - 7080' TVD ADT 7.4 AST 5.6 ART 1.8 12:00 - 14:00 2.00 DRILL DRLG INTRM1 Drill 8 1/2" hole f/ 9500' to 9540' (hard sliding) 14:00 - 14:30 0.50 DRILL CIRC INTRM1 Pump sweep around - Recip & rotate pipe 14:30 - 00:00 9.50 DRILL DRLG INTRM1 Drill 8 1/2" hole f/ 9540' to 9673' 7134'TVD ADT 5.8 AST 5.4 ART .4 Printed: 3/4/2003 11 :24:55 AM ) ) ConocoPhillipSAlaska Page 3 015 Operations Summary. Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-45 CD2-45 ROT - DRILLING doyon 1 @ ppco.com Doyon 19 Start: 11/10/2001 Rig Release: 11/29/2001 Rig Number: 19 Description of Operations Spud Date: 11/13/2001 End: Group: pate Sub . From -To Hours Code Code Phase 11120/2001 14:30 - 00:00 9.50 DRILL DRLG INTRM1 * Note: hole took approx. 50 bbls fluid @ 9640' - Pumped LCM pill 30#1 bbl Rig Pick top of Alpine C - 9610' MD 7115' TVD 11/21/2001 00:00 - 08:00 8.00 DRILL DRLG INTRM1 Drill 8 1/2" hole fl 9673' to 9787' 7157' TVD ADT 4.0 AST 3.5 ART .5 08:00 - 12:00 4.00 DRILL CIRC INTRM1 Lost returns @ 9787' - PU off btm - reduce pump rate - pumped 2 LCM pills 65 bbls total @ 30 #1 bbl - lost approx. 375 bbls - regained returns Build mud volume in pits - work pipe & circ @ 5.5 bblsl min 12:00 - 00:00 12.00 DRILL DRLG INTRM1 Drill 8 1/2" hole fl 9787' to 9890' 7166' TVD ADT 4.7 AST 4.5 ART .2 11/22/2001 00:00 - 08:00 8.00 DRILL DRLG INTRM1 Drill 8 1/2" hole fl 9890' to 9982' 7167' TVD ADT 2.7 AST 2.1 ART .6 08:00 - 09:00 1.00 DRILL CIRC INTRM1 Circulate hole clean - monitor well (static) 09:00 - 10:30 1.50 DRILL WIPR INTRM1 Wiper trip fl 9982' to 8545' - hole in good condition - monitor well (static) 10:30 - 11 :30 1.00 DRILL TRIP INTRM1 RIH fl 8645' to 9886' 11 :30 - 12:00 0.50 DRILL REAM INTRM1 Safety wash & ream fl 9886' to 9982' - pump sweep & circulate 12:00 - 14:00 2.00 DRILL CIRC INTRM1 Lost circulation - slowed pump rate - pumped 40 bbls LCM pill @ 30 #1 bbl - regained full circulation - lost approx. 250 bbls. - circulate @ 3.5 bblsl min. - to circulate out LMC pill 14:00 - 16:30 2.50 DRILL CIRC INTRM1 POOH to 9800' - continue to circulate @ 3.5 bblsl min - full returns - circulate out LCM pill - monitor well (static) - blow down top drive 16:30 - 22:00 5.50 DRILL TRIP INTRM1 POOH to run 7" casing - flow check @ 95/8" shoe 22:00 - 23:00 1.00 DRILL TRIP INTRM1 Pump dry job & continue POOH to BHA 23:00 - 00:00 1.00 DRILL TRIP INTRM1 C/O to 5" handling equip - Pull & stand back HWDP 11/23/2001 00:00 - 02:00 2.00 DRILL TRIP INTRM1 Finish pulling & standing HWDP - LD bit, motor, MWD 02:00 - 03:00 1.00 DRILL OTHR INTRM1 PU stack washer - wash stack - pull wear bushing - set test plug wI 7" test joint 03:00 - 05:00 2.00 DRILL OTHR INTRM1 Change top rams to 7" & test to 5000 psi - pull test joint & plug - set thin wall wear bushing 05:00 - 07:30 2.50 CASE RURD INTRM1 RU for 7" casing - PJSM 07:30 - 10:30 3.00 CASE RUNC INTRM1 Ran 7" 26# L-80 MBTC casing to 2731' (68 jts) 10:30 - 11 :30 1.00 CASE CIRC INTRM1 Circulate casing volume @ 2731' 11 :30 - 13:00 1.50 CASE CIRC INTRM1 Trouble with Frank's fill up tool - repair 13:00 - 16:00 3.00 CASE RUNC INTRM1 Continue running 7" 26# L-80 MBTC casing to 5850' (144 jts. total in hole) 16:00 - 17:30 1.50 CASE CIRC INTRM1 Circulate bottoms up @ 5850' @ 3 bblsl min 17:30 - 20:30 3.00 CASE RUNC INTRM1 Continue running 7" 26# L-80 MBTC casing to 8911' (220 jts. in hole) 20:30 - 22:00 1.50 CASE CIRC INTRM1 Circulate bottoms up @ 8911' @ 3 bblsl min 22:00 - 23:00 1.00 CASE RUNC INTRM1 Finish running 7" 26# L-80- MBTC casing to 9936' (245 jts. total joints ran) 23:00 - 23:30 0.50 CASE RUNC INTRM1 PU landing joint & land 7" casing wI mandel hanger in wellhead wI shoe @ 9971.74 FC @ 9885' Rig down fill up tool - RU cement head 23:30 - 00:00 0.50 CEMENTCIRC INTRM1 Establish circulation - circulate @ 1.5 bblsl min 11/24/2001 00:00 - 00:30 0.50 CEMENTCIRC INTRM1 Circulate @2.0 bbls/ min. -lost returns - monitor well - fluid level dropped 20' and remained static - Noified Drilling Team Leader 00:30 - 02:30 2.00 CEMENT PUMP INTRM1 Cemented 7" casing - Pumped 5 bbls water - test lines to 3000 psi - pumped 50 bbls ARCO spacer @ 12.5 ppg - dropped bottom plug - mixed & pumped 33.8 bbls. 15.8 ppg cement - Dropped top plug wI 20 bbls. water fl Dowell - switched to rig pupms & displaced wI 9.6 ppg mud @ 5 to 7 bbls/ min. - bumped plug wI 1200 psi - floats held - CIP @ 02:20 hrs. - No returns during job - fluid level remained static @ 20' Printed: 3/4/2003 11 ;24:55 AM ) ) ConocoPhillipsAlaska Qperatlol1sSul11mary Report· Page 4 of 5 Legal Well Name: CD2-45 Common Well Name: CD2-45 Spud Date: 11/13/2001 Event Name: ROT - DRILLING Start: 11/10/2001 End: Contractor Name: doyon1 @ppco.com Rig Release: 11/29/2001 Group: Rig Name: Doyon 19 Rig Number: 19 Date From.. To Hours Code Sub Phase Description of Operations Code 11124/2001 02:30 - 04:00 1.50 CEMENT PULD INTRM1 LD - cement head, landing joint, elevators & long bails - PU shrot bails & 5" elevators - PU stack washer - wash stack - pull thin wall wear bushing 04:00 - 05:00 1.00 DRILL OTHR INTRM1 Set pack off & test to 5000 psi for 10 mins. 05:00 - 06:00 1.00 DRILL OTHR PROD Change top pipe rams fl 7" to 31/2" x 6" & change saver sub in top drive 06:00 - 13:30 7.50 WELCTL BOPE PROD Set test plug - Test BOPE - Choke manifold valves, choke & kill line valves, floor TIW & dart valves, top drive IBOP valves, pipe rams & blind rams to 250 psi low & 5000 psi high - Hyrdil to 250 psi low & 3500 psi high - Perform accumlator recovery test - Witnessing of test waived by Jiohn Crisp AOGCC - pull test plug & set wear bushing - blow down choke & kill lines 13:30 - 16:30 3.00 DRILL PULD PROD PJSM - PU BHA # 3 - load RA source in MWD - Test MWD - 16:30 - 19:00 2.50 DRILL PULD PROD PU PBL tool - Attempt to test tool - tool would not lock open -lay down tool - observed bent cullet on latch up assembly - also found metal shavings inside tool (looks like fl recut on box) 19:00 - 22:30 3.50 DRILL OTHR PROD POOH wI BHA to check MWD - Pull RA source - pull probe - found two pieces of metal cutting fl PBL tool - Reinstall probe - load RA source - RIH - Check back up PBL tool - found metal shaving inside tool from recut also - clean out tool - PU & attempt to test - PBL tool would not lock open - as per vendors operating instructions - LD PBL sub 22:30 - 00:00 1.50 DRILL TRIP PROD PU jars & 2 jts. 4" HWDP 11/25/2001 00:00 - 03:00 3.00 DRILL TRIP PROD RIH wI BHA - PU 114 jts. 4" drill pipe fl shed 03:00 - 05:00 2.00 DRILL TRIP PROD Contiune RIH wI drill pipe fl derrick to 8990' 05:00 - 06:30 1.50 RIGMNT RSRV PROD Slip & cut drill line - service top drive 06:30 - 07:00 0.50 DRILL TRIP PROD Continue RIH to 9796' - tag up 07:00 - 08:00 1.00 DRILL CIRC PROD Circ for casing test 08:00 - 09:30 1.50 DRILL OTHR PROD RU & test 7" casing to 3500 psi for 30 mins - RD - blow down kill line 09:30 - 12:00 2.50 CEMENT DSHO PROD C/O cmt - dill cmt fl 9796 to 9885' - drill FC @ 9885' - cmt to 9970' - drill out shoe @ 9972' - cIa rat hole to 9982' 12:00 - 12:15 0.25 DRILL DRLH PROD Drill 20' new hole fl 9982' to 10,002' 7163' TVD ADT .3 ART .3 12:15 - 13:30 1.25 DRILL CIRC PROD Circ hole clean for F.I.T. 13:30 - 14:00 0.50 DRILL FIT PROD Perform F.I.T. to 12.6 ppg EMW 14:00 - 14:30 0.50 DRILL OBSV PROD Monitor well - static 14:30 - 00:00 9.50 DRILL, OTHR PROD Prep rig for OBM - Transfer LSND mud to ball mill - clean pits- Monitoring well on trip tank - well static 11/26/2001 00:00 - 02:30 2.50 DRILL OTHR PROD Continue clean pits & prep rig for OBM 02:30 - 03:00 0.50 DRILL SFTY PROD PJSM - OBM displacement prccedure 03:00 - 09:00 6.00 DRILL OTHR PROD Mix spacers - take on 580 bbls. 9.2 ppg Versaclean OBM 09:00 - 10:30 1.50 DRILL CIRC PROD Change well over to 9.2 ppg Versaclean OBM 10:30 - 11 :30 1.00 DRILL OTHR PROD Take on 240 bbls additional OBM - establish base line ECD 11 :30 - 13:00 1.50 DRILL DRLG PROD Drill 6 1/8" hole fl 10,002' to 10,036' - TVD 7160' - ADT .2 ART.2 Hole started taking fluid @ 10,007' - 100 bblsl hr while drilling - Pull up & monitor well while mixing LCM pill - lost 20 bbls I hr static 13:00 - 14:00 1.00 DRILL CIRC PROD Spot 25 bbls LCM pill wI 20 PPB LCM 14:00 - 16:00 2.00 DRILL OBSV PROD Monitor well in static mode for losses - fluid level @ flow line 16:00 - 17:00 1.00 DRILL DRLG PROD Drill to 10,038' - pumping 180 GPM - hole taking fluid @ 126 bblsl hr- pull to shoe monitor well for losses - blow down top drive - conferred wI Drilling Engineer & Team leader discuss options 17:00 - 23:00 6.00 DRILL OBSV PROD Monitor well while prep for Form -A- Set pill 23:00 - 00:00 1.00 DRILL OTHR PROD Spot Form-A-Set pill - 18 bbl Safe Surf 0 sweep - 10 bbls. weighted hi vis spacer - 30 bbls Form-A-Set pill - 11/27/2001 00:00 - 01 :30 1.50 DRILL OTHR PROD Spot Form-A-Set pill, pump out to 9784'. Printed: 3/4/2003 11 :24:55 AM ) ) ConocoPhillips .Alaskà . Page 5 of 5 Operations Summary Repprt Legal Well Name: CD2-45 Common Well Name: CD2-45 Spud Date: 11/13/2001 Event Name: ROT - DRILLING Start: 11/10/2001 End: Contractor Name: doyon1 @ppco.com Rig Release: 11/29/2001 Group: Rig Name: Doyon 19 Rig Number: 19 Date From-To Hours Code Sub Phase Description of Ope rations Code 11/27/2001 01 :30 . 06:00 4.50 DRILL OBSV PROD Down squeeze 24 bbls @ 0.5 - 2.2 bpm with 850 - 1020 psi. Shut in well 4 hours. 06:00 - 07:30 1.50 DRILL REAM PROD Wash and ream from 9784', 180 gpm, 1960 psi, started losing mud @ 10020', loss rate 98 bph. Pulled to 9941'. 07:30 - 11 :30 4.00 DRILL OBSV PROD Monitor well on trip tank, static. Develope approved suspention procedures. 11 :30 - 14:00 2.50 DRILL CIRC PROD Mix 70 bbls of 20 ppb LCM pill, pump pill @ 2.5 bpm, 880 psi. partially displace pill with 70 bbls of mud, had 35 bbls losses. 14:00 - 15:30 1.50 DRILL TRIP PROD Pump out to 9435', completing Pill displacement to bit. Monitor well, static. Blow down Top drive. 15:30·22:00 6.50 DRILL TRIP PROD POH to 8000', monitor well, static, pump dry job. Continue to POH to 2500'. 22:00 - 22:15 0.25 DRILL CIRC PROD Pipe pulling wet, attempt to circ, pipe plugged. 22:15 - 23:30 1.25 DRILL TRIP PROD POH to LWD. 23:30 - 00:00 0.50 DRILL TRIP PROD Remove source, plug in to download tools. 11/28/2001 00:00 - 01 :00 1.00 DRILL TRIP PROD Download LWD. 01 :00 - 02:30 1.50 DRILL PULD PROD LD BHA, tools plugged with LCM from Hang Off Sub to bit, clear tools and clean rig floor. 02:30 - 03:30 1.00 CMPL TN OTHR SUSPEN Rig up Schlumberger. 03:30 - 07:30 4.00 CMPL TN OTHR SUSPEN Ran 6" gauge ring/junk basket to 5197', difficult to work deeper. POH, empty junk basket, recovered 5" x 1.5" piece of casing wiper plug. 07:30 - 10:00 2.50 CMPL TN OTHR SUSPEN Rerun 6" gauge ring/junk basket difficult to work below 5440', POH. 10:00 - 13:30 3.50 CMPL TN OTHR SUSPEN MU Baker RBP, run and set on wireline COE @ 5334' WLM. POH, RD SWS. 13:30 - 14:15 0.75 CMPL TN DEOT SUSPEN Test 7" casing against RBP to 3500 psi for 30 minutes. 14:15 - 18:30 4.25 CMPL TN TRIP SUSPEN RIH slowly with Mule shoe below 4" drill pipe to 5315'. 18:30 - 21 :00 2.50 CMPL TN CIRC SUSPEN Circ hole to strip LCM from MOBM, displace MOBM with 9.6 ppg KCL brine. 21 :00 - 00:00 3.00 CMPLTN TRIP SUSPEN POH, LD excess 4" drill pipe. 11/29/2001 00:00 - 02:30 2.50 CMPLTN TRIP PROD POH, LD 20 joints and stand back 22 stands of 4" drill pipe. 02:30 - 05:00 2.50 CMPL TN RUNT PROD RU and run 57 joints of 41/2" tubing to 2497'. 05:00 - 07:00 2.00 CMPL TN FRZP PROD RU and test cement lines to 2500 psi. Freeze protect tuning and annulus to 2000" TVD with 75 bbls of diesel. Une up and allow diesel to u-tube. Clear and RD lines. 07:00 - 08:30 1.50 CMPL TN RUNT SUSPEN MU hanger and Landing joint, land kill string @ 2525'. RILD8. 08:30 - 09:30 1.00 CMPL TN SEOT SUSPEN Pull LJ, install TWC, MU LJ, test hanger seals to 5000 psi. LD LJ. 09:30 - 12:30 3.00 CMPL TN NUND SUSPEN ND BOPE, install adapter flange and tree, test to 5000 psi. Pull TWC and install BPV. Secure wellhead, released rig @ 1230 hours. Printed: 3/4/2003 11 :24:55 AM ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) yqnoqQF>hillips Alél$ka . .. Opørätion,!;...$lI111 l'Î1étry' .Report. CD2-45 CD2-45 ROT - DRILLING doyon1 @ppco.com Doyon 19 Spud Date: 11/13/2001 End: 1/6/2003 Group: Start: 12/29/2002 Rig Release: Rig Number: 19 DescriþtionOf OperatiQns . ·Date . Sub From-To HoUrs Code . Code Phase 12/29/2002 12:00 - 18:00 18:00 - 20:30 20:30 - 22:30 22:30 - 00:00 12/30/2002 00:00 - 00:30 00:30 - 01 :30 01 :30 - 03:30 03:30 - 04:30 04:30 - 05:00 05:00 - 08:00 08:00 - 13:30 13:30 - 14:30 14:30 - 15:30 15:30 - 19:30 19:30 - 21 :30 21 :30 - 22:30 12/31/2002 22:30 - 00:00 00:00 - 01 :00 01 :00 - 04:00 04:00 - 04:30 04:30 - 11 :30 11 :30 - 12:00 12:00 - 15:00 15:00 - 20:00 20:00 - 00:00 1/1/2003 00:00 - 01 :30 01 :30 - 12:00 12:00 - 00:00 1/2/2003 00:00 - 12:00 6.00 MOVE 2.50 MOVE 2.00 DRILL 1.50 DRILL 0.50 DRILL 1.00 DRILL 2.00 DRILL 1.00 DRILL 0.50 DRILL 3.00 DRILL 5.50 DRILL 1.00 DRILL 1.00 DRILL 4.00 DRILL 2.00 DRILL 1.00 DRILL 1.50 DRILL 1.00 DRILL 3.00 DRILL 0.50 DRILL 7.00 DRILL 0.50 DRILL 3.00 DRILL 5.00 DRILL 4.00 DRILL 1.50 DRILL 10.50 DRILL 12.00 DRILL 12.00 DRILL POSN MOVE RURD RIGUP OTHR PROD CIRC PROD OTHR OTHR OTHR OTHR OTHR TRIP OTHR TRIP TRIP REAM TRIP CIRC PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD PROD TRIP PROD TRI P PROD TRIP PROD CIRC PROD TRIP PROD OTHR PROD PULD PROD TRIP PROD REAM PROD CIRC PROD DRLH PROD DRLH PROD DRLH PROD Hold safety meeting. Move motor and pit complexes. Jack floor and raise cellar walls and feet. Move from CD2-28 to CD2-45. Spot and level rig. Jack floor and spot motor and pit complexes. Hook up electrical lines to subbase. Install and check safety equipment Hook up service lines and start filling pits wI water. Accept rig @ 18:00 hrs 12/29/02 Pull BPV. RIU displacement lines Displace diesel w/ water @ 3.5 bpm @ 240 psi. RID displacement lines. RID displacement lines and set 2-way check N/D tree N/U BOPE Pull2-way check, Test casing and BOPE body to 3500 psi 15 min. OK. PIU landing jt. Engage tbg hanger. Back out lockdown screws Pull hanger to floor wI 90K. UD hanger and UD 57 jts 4-1/2" tubing. Test BOPE. John Crisp, AOGCC, waived witnessing testlnstall wearbushing and blowdown choke and kill lines M/U plug retrieving tool and RIH. Tag ice pllug @ 604' POOH, UDretrieving tool and P/U bit and bit sub wI float. RIH to 670' Clean out ice plug from 670' to 1335' RIH to 5325' CBU wI heated water. Displace well wI 40 bbl Safe-O, 10 bbl mineral oil and 100 bbl MOBM Blow down topdrive. POOH from 5325' to 2862' Continue POOH wI bit fl 2862' - break off bit MU bridge plug retrieving tool & RIH slowly (flowing over) to 5253' Break circulation @ 5253' - wash down & tag bridge plug @ 5330' - release bridge plug - circ bottoms up @ 7 BMP @ 2500 psi Attempt to POOH wI bridge plug - well swabbing - Pump out fl 5330' to 1055' - POOH on trip tank fl 1055' - lay down bridge plug Clean up rig floor - Prep to MU BHA #1 MU BHA #1 - 6 1/8" - Adjust motor - & AGS - Load MWD - Change out 1 flex collar - RIH to 382' - test MWD RIH (SLM) string took weight @ 9460' (fill pipe every 2000') Wash & ream fl 9460' to 9992' - observed LCM material @ shakers fl bottoms up @ 9460' & aireated mud - checked wI explosive meter 0 % LEL - Circulate well to 8.6 ppg OBM Contiune to circulate well to 8.6 ppg in & out - shut down & monitor well for 15 mins. - static Drill 6 1/8" horizontal section fl 10038' to 10798' MD 7169 TVD ADT 5.8 hrs. ART 5.2 hrs AST .6 WOB 6/9 K RPM 60 to 80 GPM 210 @ 2780 psi Torque onloff 12000/11500 ft Ibs. String wt. PU 210 SO 145 ROT 175 Drill 6 1/8" horizontal section fl 10798' to 11,560' MD 7166' TVD ADT 7.4 ART 6.2 AST 1.2 WOB 8/10 k RPM 60/80 GPM 210 @ 3120 psi Torque onloff 13000/12000 ft Ibs String wt. PU 210 SO 140 ROT 180 Drill 6 1/8" horizontal section fl 11,560' to 12,308' MD 7158' TVD ADT 7.1 ART 6.4 AST .7 WOB 7/10 k RPM 60/80 GPM 210 @ 2780 psi Printed: 1/21/2003 9:48:41 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-45 CD2-45 ROT - DRILLING doyon1 @ppco.com Doyon 19 Hours Code Sub Code Spud Date: 11/13/2001 End: 1/6/2003 Group: Start: 12/29/2002 Rig Release: Rig Number: 19 ···Description·olOþerations 1/2/2003 12.00 DRILL DRLH PROD 00:00 - 12:00 12:00 - 00:00 12.00 DRILL DRLH PROD 1/3/2003 10.00 DRILL DRLH PROD 00:00 - 10:00 10:00 - 13:30 3.50 DRILL CIRC PROD 13:30 - 14:00 0.50 WELCTL OBSV PROD 14:00 - 14:30 0.50 DRILL CIRC PROD 14:30 - 19:00 4.50 DRILL TRIP PROD 19:00 - 23:00 4.00 DRILL CIRC PROD 23:00 - 00:00 1.00 DRILL OTHR PROD 1/4/2003 00:00 - 00:30 0.50 DRILL OTHR PROD 00:30 - 08:30 8.00 DRILL TRIP PROD 08:30 - 09:30 1.00 WELCTL OBSV PROD 09:30 - 13:30 4.00 DRILL TRIP PROD 13:30 - 14:30 1.00 RIGMNT RSRV PROD 14:30 - 23:00 8.50 DRILL TRIP PROD 23:00 - 00:00 1.00 DRILL PULD PROD 1/5/2003 00:00 - 01 :00 1.00 DRILL PULD PROD 01 :00 - 01 :30 0.50 CMPL TN OTHR CMPL TN 01 :30 - 02:30 1.00 CMPL TN RURD CMPL TN 02:30 - 11 :00 8.50 CMPL TN RUNT CMPL TN String wt. PU 240 SO 130 ROT 175 Torque onloff 125001 11000 ft Ibs. * note - @ 12,020' Resistivity drop off to below 10 ohms - begin coming up to 7138' TVD @ 90* Drill 6 1/8" horizontal section fl 12,308' to 12,880' MD 7138' TVD ADT 8.8 ART 6.9 AST 1.8 WOB 6/11 k RPM 60/80 GPM 210 @ 2790 psi String wt. PU 245 SO 125 ROT 175 Torque onloff 14000/13000 ft Ibs. * note - @ 12,550' +1- Resistivity came back into the 20+ Ohms Lost approx. 73 bbls OBM to formation last 24 hrs. Drill 6 1/8" horizontal section fl 12,880' to 13,402' MD 7138' TVD ADT 6.7 WOB 10 RPM 80 GPM 210 @ 2950 psi String wt. PU 220 SO 135 ROT 175 Torque onloff 12500/12000 ft. Ibs. Circulate hole clean & bump mud wt. to 9.2 ppg for trip margin - well has been breathing on connections while drilling with 8.9 ppg mud wt. Had CD2 DSA operator shut in injector CD2-44 Shut down pumps & monitor well - for 30 mins. - well to static after 30 mins. Circulate & prep to pump out to 7" casing shoe Pump out fl 13,402' to 13,346' - Work stuck pipe @ 13,346' - Spot 87 bbls minerial pill to reduce hydrastatic by 100 psi - continue to work stuck pipe - torque & slump drill string - jarring down - good circulation Circulate & lower mud wt. back to 8.9 ppg (mud wt. while drilling) continue to work pipe - Had DS operator start injection back into CD2-44 Pump 10 bbls minerial oil - spot 5 bbls in annulus to cover BHA - soak & work pipe Pipe came free after 30 mins. of spotting minerial oil Prep to pump out to shoe * Note - Had high line power failure for appox. 1 hr. fl 2100 to 2200 hrs Soak & work pipe - pipe came free while coming up POOH fl 13346' to 9950' - back reamed & pumped to 12,800' - Pumped out fl 12,800' to 9950' Monitor well @ 7" shoe - Well static - inspect top drive after jarring on stuck pipe Continue to POOH - pumping wi 2.5 BPM - hole taking proper fill Monitor well - static - Cut & slip drill line Continue to POOH - pumping wi 2.5 BPM to 3463' (hole taking proper fill) - monitor well static - POOH on trip tank fl 3463 to 382' - flow check - std back HWDP & jars LD BHA - XO. 3 NM flex collars, HOC - break bit Finish LD BHA - motor & MWD Clean up rig floor - RU & pull wear bushing RU to run 4 1/2" completion Run 41/2" completion - WEL, 10' pup jt., HES "XN" nipple wi RHC plug installed, 2 jts. 41/2" 12.6# L-80 IBTM tbg, Baker S-3 packer wi mill out extension, 2 jts. 41/2" 12.6# L-80 18TM tbg,Baker 41/2" CMD sliding sleeve, 2 jts. 4 1/2" 12.6# L-80 IBTM tbg, Camco GLM #1 wi Printed: 1/21/2003 9:48:41 AM ) ) CÖrioCQPhiniþs Alaska. Page 3 of 3 ·OperCiti()ns .Suml11aryReport 8.50 CMPLTN RUNT CMPLTN dummy, 37jts. 41/2" 12.6# L-80 IBTM tbg, Camco GLM #2,74 jts. 12.6# L-80 IBTM tbg, Camco GLM #3, 44 jts. 12.6# L-80 IBTM tbg, Camco BAL-O SSSV 1.00 CMPL TN RUNT CMPL TN RU control lines to SSSV & test to 5000 psi 4.50 CMPL TN RUNT CMPL TN Continue running 41/2" completion - 50 jts. 4 1/2" 12.6# L-80 tbg w/ duel control lines - MU hanger & landing jt, - hook up control lines through hanger & test to 5000 psi - Land tbg string in wellhead w/ tail @ 9417' - XN nipple @ 9404' - Packer @ 9299' - SS @ 9187' - GLM #1 @ 9073' - GLM #2 @ 7422' - GLM#3 @ 4170' - SSSV @ 2231' Run lock down screws on hanger - LD landing jt A - set TWC - MU landing jt B - test metal to metal seals on hanger to 5000 psi LD landing jt. B PU stack washer & flush BOP stack & both mud pumps ND BOPE - riser - turnbuckles - flow line Terminate control lines through wellhead - Install tree & test to 5000 psi - Pull TWC RU hard lines to tbg & annulus - squeeze manifold PJSM - Displace OBM - Pump 20 bbls minerial oil - test lines to 4000 psi - Begin diplacement w/ diesel RU lubricator - drop RHC rod/ball to set packer - RD lubricator PJSM - pressure up on tbg to 3500 psi to set packer & test tbg for 30 mins. - bleed oft tbg to 1000 psi - pressure up on 7" x 4 1/2" annulus to 3500 psi & test for 30 mins. RD hard lines & squeeze maniflod - RU FMC lubricator & set BPV - secure well Finish cleaning pits Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From ";To CD2-45 CD2-45 ROT - DRILLING doyon1 @ppco.com Doyon 19 Hours . Code . . Sub .. ...... Code . Phase· 1/5/2003 02:30 - 11 :00 11 :00 - 12:00 12:00 - 16:30 16:30 - 17:00 0.50 CMPL TN OTHR CMPL TN 17:00 - 18:00 1.00 CMPL TN OTHR CMPL TN 18:00 - 19:30 1.50 CMPL TN NUND CMPL TN 19:30 - 22:00 2.50 CMPL TN OTHR CMPL TN 22:00 - 00:00 2.00 CMPL TN FRZP CMPL TN 1/6/2003 01 :00 - 02:00 1.00 CMPL TN PCKR CMPL TN 02:00 - 04:00 2.00 CMPL TN PCKR CMPL TN 04:00 - 06:00 2.00 CMPL TN OTHR CMPL TN 06:00 - 07:00 1.00 CMPL TN OTHR CMPL TN Spud Date: 11/13/2001 End: 1/6/2003 Group: Start: 12/29/2002 Rig Release: Rig Number: 19 Dèscription .of Operations RELEASE RIG @ 0700 HRS. 1/6/2003 Move to CD2-35A Printed: 1/21/2003 9:48:41 AM ) ) ç()noco~hillips .\I~ska,lnc. C[)2-4~ (Final~ur,,~ys) Azim. SSTVD TVD N/S E/W Y X DLS V.S. (Deg) e/100ft) (ft) 0.00 0.00 0.00 -52.70 0.00 0.00 N 0.00 E 5974344.11 371728.07 E 0.00 0.00 114.00 0.00 0.00 61.30 114.00 0.00 N 0.00 E 5974344.11 N 371728.07 E 0.00 0.00 210.69 0.43 333.87 157.99 210.69 0.33 N 0.16 W 5974344.44 N 371727.92 E 0.45 -0.36 302.76 1.23 87.80 250.05 302.75 0.67 N 0.68 E 5974344.77 N 371728.76 E 1.58 -0.27 395.03 3.81 101.57 342.23 394.93 0.10 N 4.67 E 5974344.13 N 371732.74 E 2.85 2.12 486.69 6.45 107.21 433.51 486.21 2.048 12.57 E 5974341.86 N 371740.61 E 2.93 7.74 575.76 9.87 115.40 521.67 574.37 6.798 24.25 E 5974336.90 N 371752.20 E 4.05 17.45 663.64 13.35 119.92 607.74 660.44 15.09 8 39.85 E 5974328.34 N 371767.66 E 4.09 32.13 752.78 13.86 121.32 694.38 747.08 25.77 8 57.89 E 5974317.35 N 371785.51 E 0.68 50.08 844.99 13.65 121.06 783.94 836.64 37.13 8 76.65 E 5974305.68 N 371804.07 E 0.24 68.95 935.29 12.90 119.62 871.83 924.53 47.61 8 94.54 E 5974294.90 N 371821.78 E 0.91 86.64 1028.10 14.90 119.55 961.92 1014.62 58.61 8 113.93 E 5974283.56 N 371840.98 E 2.16 105.50 1123.15 18.23 119.90 1053.01 1105.71 72.05 8 137.45 E 5974269.72 N 371864.27 E 3.51 128.47 1217.47 21.09 119.14 1141.82 1194.52 87.67 8 165.07 E 5974253.63 N 371891.62 E 3.04 155.29 1312.61 21.79 113.47 1230.39 1283.09 103.04 8 196.22 E 5974237.73 N 371922.50 E 2.30 183.56 1407.46 25.00 117.08 1317.43 1370.13 119.18 8 230.23 E 5974221.01 N 371956.22 E 3.71 213.86 1502.11 28.78 118.16 1401.84 1454.54 139.05 8 268.14 E 5974200.49 N 371993.79 E 4.03 249.28 1597.72 31.69 116.25 1484.43 1537.13 161.028 310.96 E 5974177.79 N 372036.23 E 3.21 288.89 1696.57 33.24 115.12 1567.83 1620.53 184.01 8 358.78 E 5974153.99 N 372083.65 E 1.68 331.75 1791.32 36.99 113.56 1645.33 1698.03 206.44 8 408.44 E 5974130.72 N 372132.92 E 4.07 374.99 1887.55 41.61 113.17 1719.77 1772.47 230.59 8 464.38 E 5974105.61 N 372188.44 E 4.81 422.72 1982.43 44.54 112.15 1789.07 1841.77 255.54 8 524.18 E 5974079.64 N 372247.80 E 3.17 472.97 2077.63 45.94 112.76 1856.10 1908.80 281.36 8 586.64 E 5974052.76 N 372309.82 E 1.54 525.25 2173.15 46.89 112.55 1921.96 1974.66 308.01 8 650.50 E 5974025.02 N 372373.20 E 1.01 578.92 2269.17 46.54 112.86 1987.79 2040.49 334.99 8 714.98 E 5973996.94 N 372437.21 E 0.43 633.17 2363.85 47.46 111.88 2052.36 2105.06 361.34 8 779.01 E 5973969.50 N 372500.78 E 1.23 686.66 2459.15 46.84 112.21 2117.18 2169.88 387.56 8 843.77 E 5973942.17 N 372565.09 E 0.70 740.38 2554.23 46.01 112.67 2182.71 2235.41 413.85 8 907.44 E 5973914.80 N 372628.29 E 0.94 793.65 2649.22 45.36 113.53 2249.07 2301.77 440.52 8 969.95 E 5973887.07 N 372690.35 E 0.94 846.69 2721.06 45.69 112.99 2299.41 2352.11 460.76 S 1017.05 E 5973866.02 N 372737.09 E 0.71 886.79 2824.50 45.51 113.35 2371.78 2424.48 489.84 8 1084.99 E 5973835.79 N 372804.52 E 0.30 944.53 2920.21 45.69 112.99 2438.74 2491.44 516.74 8 1147.86 E 5973807.81 N 372866.92 E 0.33 997.96 3013.72 45.24 112.90 2504.33 2557.03 542.73 S 1209.24 E 5973780.78 N 372927.85 E 0.49 1049.88 3110.86 45.25 111 .87 2572.72 2625.42 569.00 8 1273.02 E 5973753.42 N 372991.17 E 0.75 1103.18 3206.29 44.84 111 .82 2640.15 2692.85 594.13 8 1335.71 E 5973727.22 N 373053.42 E 0.43 1154.95 3301.68 44.73 112.54 2707.85 2760.55 619.49 8 1397.93 E 5973700.80 N 373115.20 E 0.54 1206.72 3397.43 44.80 111 .84 2775.83 2828.53 644.96 8 1460.36 E 5973674.27 N 373177.19 E 0.52 1258.67 3491.75 44.76 111 .23 2842.78 2895.48 669.35 8 1522.16 E 5973648.83 N 373238.56 E 0.46 1309.37 3588.86 44.82 111.80 2911.70 2964.40 694.44 8 1585.81 E 5973622.65 N 373301.77 E 0.42 1361.57 3684.40 44.58 110.94 2979.61 3032.31 718.92 8 1648.39 E 5973597.09 N 373363.92 E 0.68 1412.73 3777 .66 44.07 111 .45 3046.33 3099.03 742.48 8 1709.14 E 5973572.50 N 373424.26 E 0.67 1462.21 3873.65 43.60 111 .72 3115.57 3168.27 766.94 8 1770.96 E 5973546.99 N 373485.65 E 0.53 1512.98 3965.15 44.97 1 07.53 3181.09 3233.79 788.36 8 1831.12 E 5973524.54 N 373545.44 E 3.53 1560.30 4062.56 44.96 108.12 3250.01 3302.71 809.43 8 1896.65 E 5973502.35 N 373610.60 E 0.43 1609.84 4161.35 44.81 106.75 3320.01 3372.71 830.32 S 1963.16 E 5973480.33 N 373676.74 E 0.99 1659.69 4257.02 44.50 106.38 3388.06 3440.76 849.49 8 2027.61 E 5973460.06 N 373740.85 E 0.42 1707.05 4351 .77 45.11 108.85 3455.29 3507.99 869.70 8 2091.24 E 5973438.77 N 373804.12 E 1.95 1754.93 4447.99 44.78 109.06 3523.39 3576.09 891.78 8 2155.52 E 5973415.59 N 373868.02 E 0.38 1804.78 4542.29 45.35 110.49 3590.00 3642.70 914.37 8 2218.34 E 5973391.93 N 373930.44 E 1.23 1854.38 4639.32 45.21 110.01 3658.27 3710.97 938.23 8 2283.02 E 5973366.96 N 373994.71 E 0.38 1905.98 4734.74 44.98 109.36 3725.64 3778.34 961.00 8 2346.65 E 5973343.11 N 374057.94 E 0.54 1956.12 4828.71 44.84 108.72 3792.19 3844.89 982.64 8 2409.37 E 5973320.40 N 374120.27 E 0.50 2004.84 4925.97 44.94 108.73 3861.09 3913.79 1004.67 8 2474.37 E 5973297.26 N 374184.90 E 0.10 2054.99 5021.47 44.60 109.46 3928.89 3981.59 1026.67 8 2537.93 E 5973274.17 N 374248.07 E 0.65 2104.42 5116.64 44.16 109.48 3996.91 4049.61 1048.86 8 2600.69 E 5973250.92 N 374310.43 E 0.46 2153.63 5210.27 43.92 108.77 4064.22 4116.92 1070.19 S 2662.18 E 5973228.54 N 374371.55 E 0.59 2201.50 5307.11 43.41 108.62 4134.27 4186.97 1091.62 8 2725.52 E 5973206.03 N 374434.51 E 0.54 2250.32 5400.63 44.23 111.50 4201.75 4254.45 1113.84 8 2786.32 E 5973182.78 N 374494.93 E 2.31 2298.64 5498.39 45.48 113.43 4271.06 4323.76 1140.19 8 2850.03 E 5973155.33 N 374558.18 E 1.89 2351.98 5592.29 45.30 112.51 4337.00 4389.70 1166.28 8 2911.57 E 5973128.20 N 374619.27 E 0.72 2404.06 5689.63 44.98 112.91 4405.66 4458.36 1192.92 S 2975.22 E 5973100.47 N 374682.45 E 0.44 2457.62 5785.29 45.65 114.01 4472.93 4525.63 1219.99 S 3037.61 E 5973072.33 N 374744.37 E 1.08 2510.98 5880.90 45.47 113.21 4539.88 4592.58 1247.34 8 3100.16 E 5973043.93 N 374806.44 E 0.63 2564.64 5976.33 45.45 113.21 4606.81 4659.51 1274.14 8 3162.67 E 5973016.05 N 374868.48 E 0.02 2617.81 6071.92 45.49 114.24 4673.85 4726.55 1301.56 8 3225.06 E 5972987.57 N 374930.39 E 0.77 2671.46 ) ) ConocoPhillips Alaska, Inc. CP?-45 (Final ªurveys) SSTVD TVD N/S EIW Y X DLS V.S. (ft) (ft) (ft) (ft) (ft) e/100ft) (ft) 6166.52 45.28 112.92 4740.29 4792.99 1328.50 3286.77 E 5972959.58 N 374991.63 E 1.02 2724.37 6262.40 45.00 113.74 4807.92 4860.62 1355.41 S 3349.18 E 5972931.61 N 375053.57 E 0.67 2777.59 6357.80 45.11 113.04 4875.32 4928.02 1382.22 S 3411 .15 E 5972903.75 N 375115.08 E 0.53 2830.50 6453.16 44.91 111.91 4942.73 4995.43 1408.00 S 3473.47 E 5972876.90 N 375176.94 E 0.86 2882.68 6549.14 44.63 113.08 5010.88 5063.58 1433.86 S 3535.92 E 5972849.98 N 375238.94 E 0.91 2934.99 6644.69 44.82 112.75 5078.76 5131.46 1460.04 S 3597.85 E 5972822.74 N 375300.42 E 0.31 2987.33 6740.60 44.35 113.21 5147.07 5199.77 1486.32 S 3659.83 E 5972795.40 N 375361.94 E 0.60 3039.80 6836.00 43.74 112.94 5215.64 5268.34 1512.32 S 3720.85 E 5972768.37 N 375422.50 E 0.67 3091.55 6931.58 43.19 113.11 5285.01 5337.71 1538.03 S 3781.36 E 5972741.62 N 375482.57 E 0.59 3142.81 7027.09 42.61 112.73 5354.98 5407.68 1563.35 S 3841 .24 E 5972715.28 N 375542.01 E 0.67 3193.43 7122.78 42.30 112.35 5425.58 5478.28 1588.11 S 3900.90 E 5972689.50 N 375601.23 E 0.42 3243.45 7218.29 43.57 112.32 5495.50 5548.20 1612.84 S 3961.08 E 5972663.75 N 375660.98 E 1.33 3293.68 7313.51 42.91 112.30 5564.87 5617.57 1637.60 S 4021.42 E 5972637.96 N 375720.89 E 0.69 3344.03 7408.48 44.39 112.43 5633.59 5686.29 1662.54 S 4082.04 E 5972611.98 N 375781.08 E 1.56 3394.67 7503.94 44.25 111.77 5701.88 5754.58 1687.64 S 4143.84 E 5972585.84 N 375842.43 E 0.51 3445.99 7599.60 44.94 111 .98 5770.00 5822.70 1712.66 S 4206.16 E 5972559.75 N 375904.32 E 0.74 3497.50 7695.16 46.35 111 .39 5836.81 5889.51 1737.90 S 4269.65 E 5972533.43 N 375967.37 E 1.54 3549.76 7790.55 45.61 110.49 5903.09 5955.79 1762.42 S 4333.72 E 5972507.82 N 376031.00 E 1.03 3601.65 7886.36 46.31 110.21 5969.70 6022.40 1786.37 S 4398.29 E 5972482.77 N 376095.16 E 0.76 3653.28 7982.02 45.42 110.15 6036.31 6089.01 1810.05 S 4462.73 E 5972457.98 N 376159.18 E 0.93 3704.61 8076.94 46.04 110.56 6102.57 6155.27 1833.70 S 4526.45 E 5972433.25 N 376222.49 E 0.72 3755.57 8172.19 45.39 109.75 6169.07 6221.77 1857.19 S 4590.46 E 5972408.66 N 376286.09 E 0.91 3806.53 8266.16 44.66 109.96 6235.49 6288.19 1879.77 S 4652.99 E 5972385.02 N 376348.22 E 0.79 3855.98 8363.50 44.19 109.79 6305.01 6357.71 1902.93 S 4717.06 E 5972360.76 N 376411.89 E 0.50 3906.68 8459.15 44.75 110.17 6373.27 6425.97 1925.83 S 4780.04 E 5972336.79 N 376474.46 E 0.65 3956.63 8554.26 44.12 110.14 6441 .18 6493.88 1948.77 S 4842.54 E 5972312.79 N 376536.57 E 0.66 4006.39 8648.51 43.48 110.21 6509.20 6561.90 1971.27 S 4903.78 E 5972289.24 N 376597.41 E 0.68 4055.16 8745.37 43.26 109.81 6579.61 6632.31 1994.03 S 4966.27 E 5972265.42 N 376659.51 E 0.36 4104.76 8840.95 42.82 110.66 6649.47 6702.17 2016.59 S 5027.48 E 5972241.81 N 376720.32 E 0.76 4153.58 8872.28 42.91 111 .43 6672.44 6725.14 2024.25 S 5047.37 E 5972233.82 N 376740.08 E 1.70 4169.72 8903.98 44.07 113.68 6695.44 6748.14 2032.62 S 5067.52 E 5972225.11 N 376760.07 E 6.10 4186.62 8935.87 45.33 117.20 6718.11 6770.81 2042.26 S 5087.76 E 5972215.12 N 376780.15 E 8.71 4204.69 8967.35 47.40 119.08 6739.83 6792.53 2053.01 S 5107.85 E 5972204.03 N 376800.05 E 7.87 4223.65 8999.05 48.87 121.24 6760.99 6813.69 2064.87 S 5128.25 E 5972191.82 N 376820.25 E 6.87 4243.76 9031.23 49.94 123.90 6781.93 6834.63 2078.03 S 5148.84 E 5972178.31 N 376840.61 E 7.10 4265.08 9062.08 50.95 125.17 6801.57 6854.27 2091.51 S 5168.43 E 5972164.49 N 376859.97 E 4.56 4286.22 9094.28 51.28 125.50 6821.79 6874.49 2106.01 S 5188.88 E 5972149.65 N 376880.16 E 1.30 4308.66 9126.72 52.42 127.50 6841.83 6894.53 2121.18 S 5209.38 E 5972134.13 N 376900.40 E 5.99 4331.73 9156.45 53.69 128.59 6859.70 6912.40 2135.83 S 5228.09 E 5972119.16 N 376918.86 E 5.18 4353.48 9188.51 54.76 129.92 6878.44 6931.14 2152.29 S 5248.23 E 5972102.36 N 376938.72 E 4.74 4377.50 9222.36 56.20 132.07 6897.62 6950.32 2170.58 S 5269.28 E 5972083.71 N 376959.44 E 6.74 4403.57 9252.88 57.89 133.04 6914.22 6966.92 2187.90 S 5288.14 E 5972066.07 N 376978.01 E 6.15 4427.75 9285.46 59.53 134.15 6931.14 6983.84 2207.10 S 5308.30 E 5972046.53 N 376997.84 E 5.82 4454.20 9315.38 61.22 136.26 6945.94 6998.64 2225.56 S 5326.62 E 5972027.76 N 377015.84 E 8.34 4479.13 9349.02 62.62 137.67 6961.77 7014.47 2247.25 S 5346.87 E 5972005.72 N 377035.72 E 5.57 4507.82 9380.92 63.49 137.43 6976.23 7028.93 2268.24 S 5366.06 E 5971984.41 N 377054.55 E 2.81 4535.38 9413.23 63.96 138.20 6990.53 7043.23 2289.70 S 5385.52 E 5971962.62 N 377073.63 E 2.59 4563.49 9445.70 65.37 138.88 7004.42 7057.12 2311.70 S 5404.95 E 5971940.29 N 377092.68 E 4.74 4592.06 9476.04 66.47 140.46 7016.80 7069.50 2332.81 S 5422.87 E 5971918.87 N 377110.24 E 5.98 4619.14 9508.79 67.25 141 .84 7029.67 7082.37 2356.27 S 5441.76 E 5971895.10 N 377128.73 E 4.55 4648.74 9538.52 68.50 143.33 7040.87 7093.57 2378.14 S 5458.49 E 5971872.94 N 377145.08 E 6.26 4675.92 9571.98 70.30 144.17 7052.64 7105.34 2403.40 S 5477.01 E 5971847.37 N 377163.17 E 5.87 4706.93 9599.32 71.95 144.77 7061 .49 7114.19 2424.45 S 5492.04 E 5971826.07 N 377177.84 E 6.38 4732.59 9641.81 74.32 146.66 7073.81 7126.51 2458.05 S 5514.94 E 5971792.08 N 377200.16 E 7.02 4773.02 9672.96 76.35 147.03 7081.70 7134.40 2483.27 S 5531.42 E 5971766.58 N 377216.20 E 6.62 4803.04 9699.37 77.35 148.25 7087.71 7140.41 2505.00 S 5545.19 E 5971744.62 N 377229.59 E 5.88 4828.69 9730.84 78.24 148.79 7094.36 7147.06 2531.23 S 5561.25 E 5971718.12 N 377245.21 E 3.29 4859.40 9762.96 79.67 148.67 7100.51 7153.21 2558.17 S 5577.61 E 5971690.90 N 377261 .11 E 4.47 4890.88 9794.87 81.78 150.16 7105.66 7158.36 2585.28 S 5593.63 E 5971663.52 N 377276.66 E 8.06 4922.34 9828.64 83.84 151.57 7109.88 7162.58 2614.55 S 5609.94 E 5971633.98 N 377292.47 E 7.37 4955.84 9858.24 86.13 150.87 7112.47 7165.17 2640.39 S 5624.14 E 5971607.90 N 377306.22 E 8.09 4985.32 9890.49 88.64 151.28 7113.94 7166.64 2668.58 S 5639.72 E 5971579.44 N 377321.32 E 7.89 5017.53 9908.02 89.60 150.85 7114.21 7166.91 2683.92 S 5648.20 E 5971563.96 N 377329.53 E 6.00 5035.06 10038.11 90.92 149.29 7113.62 7166.32 2796.66 S 5713.10 E 5971450.13 N 377392.50 E 1.57 5165.08 10128.14 89.32 149.24 7113.43 7166.13 2874.04 S 5759.11 E 5971371.98 N 377437.18 E 1.78 5255.02 ') ) Con()coPhillip~ Alaska, Inc. CD2-45 (Final Surveys} Azim. X DLS v.s. (ft) (Deg) (ft) (0/100ft) (ft) 10227.59 88.89 150.79 7114.99 7167.69 2960.17 5808.81 5971285.01 N 377485.39 E 1.62 5354.41 10322.71 89.26 149.34 7116.52 7169.22 3042.58 S 5856.27 E 5971201.80 N 377531.43 E 1.57 5449.47 10418.57 89.75 150.32 7117.35 7170.05 3125.45 S 5904.44 E 5971118.11 N 377578.18 E 1.14 5545.27 10510.34 89.94 151.01 7117.60 7170.30 3205.45 S 5949.40 E 5971037.35 N 377621.77 E 0.78 5637.02 10605.21 90.31 150.29 7117.39 7170.09 3288.15 S 5995.90 E 5970953.88 N 377666.84 E 0.85 5731.87 10699.01 90.25 150.06 7116.93 7169.63 3369.52 S 6042.55 E 5970871.72 N 377712.10 E 0.25 5825.63 10799.05 90.06 148.77 7116.66 7169.36 3455.64 S 6093.45 E 5970784.74 N 377761.52 E 1.30 5925.58 10894.66 90.00 149.1 0 7116.61 7169.31 3537.54 S 6142.79 E 5970702.01 N 377809.44 E 0.35 6021.08 10990.40 89.45 149.19 7117.07 7169.77 3619.73 S 6191.89 E 5970618.99 N 377857.13 E 0.58 6116.71 11085.48 89.88 150.69 7117.63 7170.33 3702.01 S 6239.51 E 5970535.90 N 377903.34 E 1.64 6211.74 11181.10 90.12 153.05 7117.63 7170.33 3786.33 S 6284.59 E 5970450.83 N 377946.97 E 2.48 6307.35 11276.75 90.55 153.40 7117.07 7169.77 3871.73 S 6327.68 E 5970364.71 N 377988.59 E 0.58 6402.97 11372.08 90.31 152.53 7116.35 7169.05 3956.64 S 6371.01 E 5970279.07 N 378030.46 E 0.95 6498.28 11467.59 91.11 153.56 7115.17 7167.87 4041.76 S 6414.30 E 5970193.22 N 378072.29 E 1.37 6593.75 11559.82 90.49 151.85 7113.88 7166.58 4123.71 S 6456.59 E 5970110.55 N 378113.17 E 1.97 6685.96 11655.58 90.06 152.89 7113.42 7166.12 4208.55 S 6500.99 E 5970024.97 N 378156.12 E 1.18 6781.71 11749.14 90.68 152.72 7112.82 7165.52 4291.76 S 6543.75 E 5969941.04 N 378197.45 E 0.69 6875.25 11846.15 89.82 151.36 7112.40 7165.10 4377.45 S 6589.23 E 5969854.59 N 378241.46 E 1.66 6972.26 11940.17 89.94 151.03 7112.59 7165.29 4459.83 S 6634.54 E 5969771.44 N 378285.34 E 0.37 7066.27 12035.68 90.00 151.17 7112.64 7165.34 4543.45 S 6680.69 E 5969687.05 N 378330.06 E 0.16 7161.78 12131.64 91.60 151.19 7111.30 7164.00 4627.51 S 6726.95 E 5969602.20 N 378374.87 E 1.67 7257.72 12227.88 92.15 149.98 7108.15 7160.85 4711.30 S 6774.19 E 5969517.62 N 378420.67 E 1.38 7353.88 12326.62 90.92 149.58 7105.51 7158.21 4796.59 S 6823.87 E 5969431.49 N 378468.89 E 1.31 7452.53 12422.20 91.54 149.22 7103.46 7156.16 4878.84 S 6872.51 E 5969348.42 N 378516.11 E 0.75 7548.00 12517.63 92.96 149.14 7099.71 7152.41 4960.73 S 6921.36 E 5969265.71 N 378563.56 E 1.49 7643.25 12612.96 92.65 149.83 7095.04 7147.74 5042.75 S 6969.71 E 5969182.87 N 378610.50 E 0.79 7738.39 12708.19 92.09 150.38 7091.11 7143.81 5125.24 S 7017.13 E 5969099.58 N 378656.50 E 0.82 7833.50 12803.54 91.66 149.37 7087.99 7140.69 5207.67 S 7064.96 E 5969016.35 N 378702.91 E 1.15 7928.74 12899.40 90.62 149.91 7086.08 7138.78 5290.36 S 7113.40 E 5968932.84 N 378749.93 E 1.22 8024.52 12991.26 90.25 150.61 7085.38 7138.08 5370.12 S 7158.97 E 5968852.31 N 378794.13 E 0.86 8116.34 13085.39 89.69 150.30 7085.43 7138.13 5452.01 S 7205.38 E 5968769.64 N 378839.14 E 0.68 8210.44 13182.10 89.94 150.45 7085.74 7138.44 5536.08 S 7253.19 E 5968684.77 N 378885.50 E 0.30 8307.12 13280.91 90.25 150.85 7085.58 7138.28 5622.20 S 7301.62 E 5968597.83 N 378932.45 E 0.51 8405.91 13323.65 90.18 151.16 7085.42 7138.12 5659.59 S 7322.34 E 5968560.09 N 378952.52 E 0.74 8448.65 13402.00 90.18 151.16 7085.17 7137.87 5728.22 S 7360.13 E 5968490.83 N 378989.13 E 0.00 8526.99 ) AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 ) 09-Jan-03 Re: Distribution of Survey Data for Well CD2-45 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 'MD 'MD 13,402.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED JAN 1 5 2003 Alaska Uf¡ & ~s Cons. Comrnlllian Anchorage aÒJ-d/~ ci ~ ~ {. Iß Sperry-Sun Drilling Services - Alaska North Slope North Slope, Alaska Alpine CD-2 CD2-45 Job No. AKZZ22201, Surveyed: 3 January, 2003 Survey Report 8 January, 2003 ~ Your Ref: API 501032039500 Surface Coordinates: 5974344.11 N, 371728.07 E (70020'17.3042" N, 151002' 27.0046" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 974344.11 N, 128271.93 W (Grid) Surface Coordinates relative to Structure: 98.60 S, 12.27 E (True) Kelly Bushing: 52. 70ft above Mean Sea Level Elevation relative to Project V Reference: 52. 70ft Elevation relative to Structure: 52. 70ft spe............y-sur"1 DRILLING SeRVIc:es A Halliburton Company Survey Ref: svy9965 Sperry-Sun Drilling Services Survey Report for Alpine CD-2 . CD2-45 Your Ref: AP/501032039500 Job No. A KZZ2220 1 , Surveyed: 3 January, 2003 North Slope, Alaska A/aska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) r/100ft) 0.00 0.000 0.000 -52.70 0.00 0.00 N 0.00 E 5974344.11 N 371728.07 E 0.00 AK-6 BP-'FR-AK 114.00 0.000 0.000 61.30 114.00 0.00 N 0.00 E 5974344.11 N 371728.07 E 0.000 0.00 210.69 0.430 333.870 157.99 210.69 0.33 N 0.16W 5974344.44 N 371727.92 E 0.445 -0.36 302.76 1.230 87.800 250.05 302.75 0.67 N 0.68 E 5974344.77 N 371728.76 E 1.584 -0.27 ~-- 395.03 3.810 101.570 342.23 394.93 0.10 N 4.67 E 5974344.13 N 371732.74 E 2.852 2.12 486.69 6.450 107.210 433.51 486.21 2.048 12.57 E 5974341.86 N 371740.61 E 2.929 7.74 575.76 9.870 115.400 521.67 574.37 6.798 24.25 E 5974336.90 N 371752.20 E 4.046 17.45 663.64 13.350 119.920 607.74 660.44 15.09 8 39.85 E 5974328.34 N 371767.66 E 4.090 32.13 752.78 13.860 121.320 694.38 747.08 25.778 57.89 E 5974317.35 N 371785.51 E 0.681 50.08 844.99 13.650 121.060 783.94 836.64 37.138 76.65 E 5974305.68 N 371804.07 E 0.237 68.95 935.29 12.900 119.620 871.83 924.53 47.608 94.54 E 5974294.89 N 371821.78 E 0.908 86.64 1028.10 14.900 119.550 961.92 1014.62 58.61 8 113.93 E 5974283.56 N 371840.98 E 2.155 105.50 1123.15 18.230 119.900 1053.01 1105.71 72.05 8 137.45 E 5974269.72 N 371864.27 E 3.505 128.4 7 1217.47 21.090 119.140 1141.82 1194.52 87.678 165.07 E 5974253.63 N 371891.62 E 3.044 155.29 1312.61 21.790 113.470 1230.39 1283.09 103.04 8 196.22 E 5974237.72 N 371922.50 E 2.298 183.56 1407.46 25.000 117.080 131 7.43 1370.13 119.188 230.23 E 5974221.01 N 371956.22 E 3.705 213.86 1502.11 28.780 118.160 1401.84 1454.54 139.058 268.14 E 5974200.49 N 371993.79 E 4.027 249.28 1597.72 31.690 116.250 1484 .43 1537.13 161.02 8 310.96 E 5974177.79 N 372036.23 E 3.205 288.89 1696.57 33.240 115.120 1567.83 1620.53 184.01 8 358.78 E 5974153.99 N 372083.65 E 1.684 331.75 1791.32 36.990 113.560 1645.33 1698.03 206.448 408.44 E 5974130.72 N 372132.92 E 4.069 374.99 1887.55 41.610 113.170 1719.77 1772.4 7 230.59 8 464.38 E 5974105.61 N 372188.44 E 4.808 422.72 ~ 1982.43 44.540 112.150 1789.07 1841 .77 255.54 8 524.18 E 5974079.64 N 372247.80 E 3.174 472.97 2077.63 45.940 112.760 1856.10 1908.80 281.36 8 586.64 E 5974052.75 N 372309.82 E 1.539 525.25 2173.15 46.890 112.550 1921.96 1974.66 308.01 8 650.50 E 5974025.02 N 372373.20 E 1.007 578.92 2269.17 46.540 112.860 1987.79 2040.49 334.99 8 714.98 E 5973996.94 N 372437.21 E 0.434 633.17 2363.85 47.460 111.880 2052.36 2105.06 361.34 S 779.01 E 5973969.50 N 372500.78 E 1.232 686.66 2459.15 46.840 112.210 2117.17 2169.87 387.56 S 843.77 E 5973942.17 N 372565.09 E 0.698 740.38 2554.23 46.010 112.670 2182.71 2235.41 413.85 S 907.44 E 5973914.80 N 372628.29 E 0.941 793.64 2649.22 45.360 113.530 2249.07 2301.77 440.51 S 969.95 E 5973887.07 N 372690.35 E 0.942 846.69 2721.06 45.690 112.990 2299.41 2352.11 460.76 S 1017.05 E 5973866.02 N 372737.09 E 0.706 886.79 2824.50 45.510 113.350 2371.78 2424.48 489.84 8 1084.99 E 5973835.79 N 372804.52 E 0.303 944.53 2920.21 45.690 112.990 2438.74 2491.44 516.748 1147.86 E 5973807.81 N 372866.92 E 0.328 997.96 3013.72 45.240 112.900 2504.33 2557.03 542.73 S 1209.24 E 5973780.78 N 372927.85 E 0.486 1049.88 3110.86 45.250 111.870 2572.72 2625.42 569.00 8 1273.02 E 5973753.42 N 372991.17 E 0.753 1103.17 3206.29 44.840 111.820 2640.15 2692.85 594.12 S 1335.70 E 5973727.22 N 373053.42 E 0.431 1154.95 ____ ________,_ ___ _ _ _ ___n _ ___ .______ ___________~__. 8 January, 2003 - 14:06 Page 20f7 DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for A/pine CD-2 - CD2-45 Your Ref: AP/501032039500 Job No. AKZZ22201, Surveyed: 3 January, 2003 North Slope, A/aska A/aska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 3301.68 44.730 112.540 2707.85 2760.55 619.49 5 1397.93 E 5973700.80 N 373115.20 E 0.544 1206.72 3397.43 44.800 111.840 2775.83 2828.53 644.96 5 1460.36 E 5973674.27 N 373177.19 E 0.520 125R.67 3491.75 44.760 111 .230 2842.78 2895.48 669.345 1522.16 E 5973648.82 N 373238.56 E 0.458 1309.37 3588.86 44.820 111.800 2911.70 2964.40 694.44 5 1585.81 E 5973622.65 N 373301.77 E 0.418 1361.57 ,- 3684.40 44.580 110.940 2979.61 3032.31 718.925 1648.39 E 5973597.09 N 373363.92 E 0.681 1412.73 3777.66 44.070 111 .450 3046.33 3099.03 742.48 5 1709.14 E 5973572.50 N 373424.26 E 0.667 1462.21 3873.65 43.600 111.720 3115.57 3168.27 766.94 S 1770.96 E 5973546.99 N 373485.65 E 0.527 1512.98 3965.15 44.970 107.530 3181.09 3233.79 788.36 5 1831.12 E 5973524.54 N 373545.44 E 3.530 1560.30 4062.56 44.960 108.120 3250.01 3302.71 809.43 5 1896.65 E 5973502.35 N 373610.60 E 0.428 1609.84 4161.35 44.810 106.750 3320.00 3372.70 830.32 5 1963.16 E 5973480.33 N 373676.74 E 0.990 1659.69 4257.02 44.500 106.380 3388.06 3440.76 849.49 5 2027.61 E 5973460.06 N 373740.85 E 0.423 1707.05 4351.77 45.110 108.850 3455.29 3507.99 869.70 5 2091.24 E 5973438.76 N 373804.12 E 1.946 1754.93 4447.99 44.780 109.060 3523.39 3576.09 891.78 S 2155.52 E 5973415.59 N 373868.02 E 0.376 1804.78 4542.29 45.350 110.490 3590.00 3642.70 914.375 2218.34 E 5973391.93 N 373930.44 E 1.232 1854.38 4639.32 45.210 110.010 3658.27 3710.97 938.23 S 2283.02 E 5973366.96 N 373994.71 E 0.380 1905.98 4734.74 44.980 109.360 3725.63 3778.33 961.00 5 2346.65 E 5973343.11 N 374057.94 E 0.539 1956.12 4828.71 44.840 108.720 3792.19 3844.89 982.64 S 2409.37 E 5973320.40 N 374120.27 E 0.503 2004.84 4925.97 44.940 108.730 3861.09 3913.79 1004.67 S 2474.37 E 5973297.26 N 374184.90 E 0.103 2054.99 5021.47 44.600 1 09.460 3928.89 3981 .59 1026.67 5 2537.93 E 5973274.17 N 374248.07 E 0.645 2104.42 5116.64 44.160 109.480 3996.91 4049.61 1048.86 S 2600.69 E 5973250.91 N 374310.43 E 0.463 2153.63 5210.27 43.920 108.770 4064.22 4116.92 1070.19 S 2662.18 E 5973228.54 N 374371.55 E 0.586 2201.50 --- 5307.11 43.410 108.620 4134.27 4186.97 1091.62 5 2725.51 E 5973206.03 N 374434.51 E 0.537 2250.32 5400.63 44.230 111 .500 4201.75 4254.45 1113.83 S 2786.32 E 5973182.78 N 374494.93 E 2.305 2298.64 5498.39 45.480 113.430 4271.06 4323.76 1140.195 2850.03 E 5973155.33 N 374558.18 E 1.890 2351.98 5592.29 45.300 112.510 4337.00 4389.70 1166.28 S 2911.57 E 5973128.20 N 374619.27 E 0.723 2404.06 5689.63 44.980 112.910 4405.66 4458.36 1192.925 2975.22 E 5973100.47 N 374682.45 E 0.439 2457.62 5785.29 45.650 114.010 4472.93 4525.63 1219.99 S 3037.61 E 5973072.33 N 374744.37 E 1.077 2510.98 5880.90 45.470 113.210 4539.87 4592.57 1247.335 3100.16E 5973043.93 N 374806.44 E 0.626 2564.64 5976.33 45.450 113.210 4606.81 4659.51 1274.145 3162.67 E 5973016.05 N 374868.48 E 0.021 2617.81 6071.92 45.490 114.240 4673.85 4726.55 1301.56 S 3225.06 E 5972987.57 N 374930.39 E 0.769 2671.46 6166.52 45.280 112.920 4740.29 4792.99 1328.50 S 3286.77 E 5972959.58 N 374991.63 E 1.018 2724.37 6262.40 45.000 113.740 4807.92 4860.62 1355.41 5 3349.17 E 5972931.61 N 375053.57 E 0.673 2777.59 6357.80 45.110 113.040 4875.31 4928.01 1382.22 S 3411.15 E 5972903.75 N 375115.07 E 0.532 2830.50 6453.16 44.910 111.910 4942.73 4995.43 1408.00 S 3473.46 E 5972876.90 N 375176.94 E 0.864 2882.68 6549.14 44.630 113.080 5010.87 5063.57 1433.86 S 3535.92 E 5972849.98 N 375238.94 E 0.907 2934.99 ----- ~-----------'----- ... 8 January, 2003 - 14:06 Page 3 of7 Ðri1/QlJest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for Alpine CD-2 - CD2-45 Your Ref: API 501032039500 Job No. AKZZ22201, Surveyed: 3 January, 2003 North Slope, Alaska A/aska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 6644.69 44.820 112.750 5078.76 5131.46 1460.04 S 3597.85 E 5972822.74 N 375300.42 E 0.314 2987.33 6740.60 44.350 113.210 5147.07 5199.77 1486.32 S 3659.83 E 5972795.40 N 375361.94 E 0.595 3039.80 6836.00 43.740 112.940 5215.64 5268.34 1512.32 S 3720.85 E 5972768.37 N 375422.50 E 0.669 3091.55 6931 .58 43.190 113.110 5285.01 5337.71 1538.03 S 3781.36 E 5972741.62 N 375482.57 E 0.588 3142.81 /- 7027.09 42.610 112.730 5354.98 5407.68 1563.35 S 3841.24 E 5972715.28 N 375542.01 E 0.665 3193.43 7122.78 42.300 112.350 5425.58 5478.28 1588.11 S 3900.90 E 5972689.50 N 375601.23 E 0.420 3243.45 7218.29 43.570 112.320 5495.50 5548.20 1612.84 S 3961.08 E 5972663.75 N 375660.98 E 1.330 3293.68 7313.51 42.910 112.300 5564.87 5617.57 1637.60 S 4021.42 E 5972637.96 N 375720.89 E 0.693 3344.03 7408.48 44.390 112.430 5633.59 5686.29 1662.54 S 4082.04 E 5972611.98 N 375781.08 E 1.561 3394.67 7503.94 44.250 111.770 5701.88 5754.58 1687.63 S 4143.84 E 5972585.84 N 375842.43 E 0.505 3445.99 7599.60 44.940 111.980 5770.00 5822.70 1712.66 S 4206.16 E 5972559.75 N 375904.32 E 0.738 3497.50 7695.16 46.350 111.390 5836.81 5889.51 1737.90 S 4269.65 E 5972533.43 N 375967.37 E 1.540 3549.76 7790.55 45.610 110.490 5903.09 5955.79 1762.42 S 4333.72 E 5972507.82 N 376031.00 E 1.031 3601.65 7886.36 46.310 110.210 5969.70 6022.40 1786.37 S 4398.29 E 5972482.76 N 376095.16 E 0.760 3653.28 7982.02 45.420 110.150 6036.31 6089.01 1810.05 S 4462.73 E 5972457.98 N 376159.18 E 0.931 3704.61 8076.94 46.040 110.560 6102.57 6155.27 1833.70 S 4526.45 E 5972433.25 N 376222.49 E 0.723 3755.57 8172.19 45.390 109.750 6169.07 6221.77 1857.19 S 4590.46 E 5972408.66 N 376286.09 E 0.914 3806.53 8266.16 44.660 109.960 6235.49 6288.19 1879.77 S 4652.99 E 5972385.02 N 376348.22 E 0.793 3855.98 8363.50 44.190 109.790 6305.01 6357.71 1902.93 S 4717.06 E 5972360.76 N 376411.89 E 0.498 3906.68 8459.15 44.750 110.170 6373.26 6425.96 1925.83 S 4780.04 E 5972336.79 N 376474.46 E 0.648 3956.63 8554.26 44.120 110.140 6441 .18 6493.88 1948.77 S 4842.54 E 5972312.78 N 376536.57 E 0.663 4006.39 ~ 8648.51 43.480 110.210 6509.20 6561.90 1971.27 S 4903.78 E 5972289.24 N 376597.41 E 0.681 4055.16 8745.37 43.260 109.810 6579.61 6632.31 1994.03 S 4966.27 E 5972265.42 N 376659.51 E 0.363 4104.76 8840.95 42.820 110.660 6649.47 6702.17 2016.59 S 5027.48 E 5972241.81 N 376720.32 E 0.762 4153.58 8872.28 42.910 111 .430 6672.44 6725.14 2024.25 S 5047.37 E 5972233.82 N 376740.08 E 1.696 4169.72 8903.98 44.070 113.680 6695.43 6748.13 2032.62 S 5067.52 E 5972225.10 N 376760.07 E 6.103 4186.62 8935.87 45.330 117.200 6718.10 6770.80 2042.26 S 5087.76 E 5972215.12 N 376780.15 E 8.710 4204.69 8967.35 47.400 119.080 6739.83 6792.53 2053.01 S 5107.85 E 5972204.03 N 376800.05 E 7.868 4223.65 8999.05 48.870 121.240 6760.98 6813.68 2064.87 S 5128.25 E 5972191.82 N 376820.25 E 6.874 4243.75 9031 .23 49.940 123.900 6781.93 6834.63 2078.02 S 5148.84 E 5972178.31 N 376840.61 E 7.102 4265.08 9062.08 50.950 125.170 6801.57 6854.27 2091.51 S 5168.43 E 5972164.49 N 376859.97 E 4.560 4286.22 9094.28 51.280 125.500 6821.79 6874.49 2106.01 S 5188.88 E 5972149.65 N 376880.16 E 1.299 4308.66 9126.72 52.420 127.500 6841.83 6894.53 2121.18 S 5209.38 E 5972134.13 N 376900.40 E 5.988 4331.73 9156.45 53.690 128.590 6859.70 6912.40 2135.83 S 5228.09 E 5972119.16 N 376918.86 E 5.180 4353.48 9188.51 54.760 129.920 6878.44 6931.14 2152.29 S 5248.23 E 5972102.36 N 376938.71 E 4.740 4377.50 -------------. ---- 8 January, 2003 - 14:06 Page 4 of 7 DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for A/pine CD-2 . CD2-45 Your Ref: AP/501032039500 Job No. AKZZ22201, Surveyed: 3 January, 2003 North Slope, Alaska A/aska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 9222.36 56.200 132.070 6897.62 6950.32 2170.58 S 5269.28 E 5972083.71 N 376959.44 E 6.744 4403.57 9252.88 57.890 133.040 6914.22 6966.92 2187.90 S 5288.14 E 5972066.07 N 376978.01 E 6.146 4427.75 9285.46 59.530 134.150 6931.14 6983.84 2207.10 S 5308.30 E 5972046.53 N 376997.84 E 5.815 4454.20 9315.38 61 .220 136.260 6945.94 6998.64 2225.56 S 5326.62 E 5972027.76 N 377015.84 E 8.335 4479.13 /- 9349.02 62.620 137.670 6961.77 7014.47 2247.25 S 5346.87 E 5972005.72 N 377035.72 E 5.567 4507.82 9380.92 63.490 137.430 6976.22 7028.92 2268.24 S 5366.06 E 5971984.41 N 377054.55 E 2.809 4535.38 9413.23 63.960 138.200 6990.53 7043.23 2289.70 S 5385.52 E 5971962.62 N 377073.63 E 2.585 4563.49 9445.70 65.370 138.880 7004.42 7057.12 2311.70 S 5404.95 E 5971940.29 N 377092.68 E 4.737 4592.06 9476.04 66.4 70 140.460 7016.80 7069.50 2332.81 S 5422.87 E 5971918.87 N 377110.24 E 5.979 4619.14 9508.79 67.250 141.840 7029.67 7082.37 2356.27 S 5441.76 E 5971895.10 N 377128.73 E 4.548 4648.74 9538.52 68.500 143.330 7040.87 7093.57 2378.14 S 5458.49 E 5971872.94 N 377145.08 E 6.263 4675.92 9571.98 70.300 144.170 7052.64 7105.34 2403.40 S 5477.01 E 5971847.37 N 377163.17 E 5.870 4706.93 9599.32 71.950 144.770 7061.49 7114.19 2424.45 S 5492.04 E 5971826.07 N 377177.84 E 6.382 4732.59 9641.81 74.320 146.660 7073.81 7126.51 2458.05 S 5514.94 E 5971792.08 N 377200.16 E 7.016 4773.02 9672.96 76.350 147.030 7081.70 7134.40 2483.27 S 5531.42 E 5971766.58 N 377216.20 E 6.617 4803.04 9699.37 77.350 148.250 7087.71 7140.41 2505.00 S 5545.19 E 5971744.62 N 377229.59 E 5.880 4828.69 9730.84 78.240 148.790 7094.36 7147.06 2531.23 S 5561.25 E 5971718.12 N 377245.20 E 3.288 4859.40 9762.96 79.670 148.670 7100.51 7153.21 2558.17 S 5577.61 E 5971690.90 N 377261.10 E 4.467 4890.88 9794.87 81.780 150.160 7105.66 7158.36 2585.28 S 5593.63 E 5971663.52 N 377276.66 E 8.060 4922.34 9828.64 83.840 151.570 7109.88 7162.58 2614.55 S 5609.94 E 5971633.98 N 377292.4 7 E 7.374 4955.84 9858.24 86.130 150.870 7112.47 7165.17 2640.39 S 5624.14 E 5971607.90 N 377306.22 E 8.087 4985.32 ,-. 9890.49 88.640 151.280 7113.94 7166.64 2668.58 S 5639.72 E 5971579.44 N 377321.31 E 7.886 5017.53 9908.02 89.600 150.850 7114.21 7166.91 2683.92 S 5648.20 E 5971563.96 N 377329.53 E 6.000 5035.06 10038.11 90.920 149.290 7113.62 7166.32 2796.66 S 5713.10 E 5971450.13 N 377392.50 E 1.571 5165.08 10128.14 89.320 149.240 7113.43 7166.13 2874.04 S 5759.11 E 5971371.98 N 377437.18 E 1.778 5255.02 10227.59 88.890 150.790 7114.99 7167.69 2960.16 S 5808.81 E 5971285.01 N 377485.39 E 1.617 5354.41 10322.71 89.260 149.340 7116.52 7169.22 3042.58 S 5856.27 E 5971201.80 N 377531.43 E 1.573 5449.47 10418.57 89.750 150.320 7117.35 7170.05 3125.45 S 5904.44 E 5971118.11 N 377578.18 E 1.143 5545.27 10510.34 89.940 151.010 7117.60 7170.30 3205.45 S 5949.40 E 5971037.35 N 377621.77 E 0.780 5637.02 10605.21 90.310 150.290 7117.39 7170.09 3288.15 S 5995.90 E 5970953.88 N 377666.84 E 0.853 5731.87 10699.01 90.250 150.060 7116.93 7169.63 3369.52 S 6042.55 E 5970871.72 N 377712.10 E 0.253 5825.63 10799.05 90.060 148.770 7116.66 7169.36 3455.64 S 6093.45 E 5970784.74 N 377761.52 E 1.303 5925.58 10894.66 90.000 149.100 7116.61 7169.31 3537.54 S 6142.79 E 5970702.01 N 377809.44 E 0.351 6021.08 10990.40 89.450 149.190 7117.07 7169.77 3619.73 S 6191.89 E 5970618.99 N 377857.13 E 0.582 6116.71 11085.48 89.880 150.690 7117.63 7170.33 3702.01 S 6239.51 E 5970535.90 N 377903.34 E 1.641 6211.74 ______ _ ___._.__ __ _.4_ _ _. .._________ ___ 8 January, 2003 - 14:06 Page 5 of7 DrillQ/Jest 3.03.02.004 Dri/lQllest 3.03.02.004 Page 60f7 8 January, 2003 - 14:06 -- ------ - -- --,-- -------~ Sperry-Sun Drilling Services Survey Report for Alpine CD·2 - CD2-45 Your Ref: AP/501032039500 Job No. AKZZ22201, Surveyed: 3 January, 2003 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 11181.10 90.120 153.050 711 7.63 7170.33 3786.33 8 6284.59 E 5970450.83 N 377946.97 E 2.481 6307.35 11276.75 90.550 153.400 7117.07 7169.77 3871.73 S 6327.68 E 5970364.71 N 377988.59 E 0.580 6402.97 11372.08 90.310 152.530 7116.35 7169.05 3956.64 8 6371.01 E 5970279.07 N 378030.46 E 0.947 6498.28 11467.59 91.110 153.560 7115.17 7167.87 4041.76 S 6414.30 E 5970193.22 N 378072.29 E 1.365 6593.75 11559.82 90.490 151.850 7113.88 7166.58 4123.71 8 6456.59 E 5970110.55 N 378113.17E 1.972 6685.96 11655.58 90.060 152.890 7113.42 7166.12 4208.55 S 6500.99 E 5970024.97 N 378156.12 E 1.175 6781.71 11749.14 90.680 152.720 7112.82 7165.52 4291.76 S 6543.75 E 5969941.04 N 378197.45 E 0.687 6875.25 11846.15 89.820 151.360 7112.39 7165.09 4377.45 S 6589.23 E 5969854.59 N 378241.46 E 1.659 6972.26 11940.17 89.940 151.030 7112.59 7165.29 4459.83 S 6634.53 E 5969771.44 N 378285.34 E 0.373 7066.27 12035.68 90.000 151.170 7112.64 7165.34 4543.45 S 6680.69 E 5969687.05 N 378330.06 E 0.159 7161.78 121 31 .64 91.600 151.190 7111.30 7164.00 4627.51 S 6726.95 E 5969602.20 N 378374.87 E 1.667 7257.72 12227.88 92.150 149.980 7108.15 7160.85 4711.308 6774.19 E 5969517.62 N 378420.67 E 1.380 7353.88 12326.62 90.920 149.580 7105.51 7158.21 4796.59 S 6823.86 E 5969431.49 N 378468.88 E 1.310 7452.53 12422.20 91.540 149.220 7103.46 7156.16 4878.84 8 6872.51 E 5969348.42 N 378516.11 E 0.750 7548.00 12517.63 92.960 149.140 7099.71 7152.41 4960.73 S 6921.36 E 5969265.71 N 378563.56 E 1 .490 7643.25 12612.96 92.650 149.830 7095.04 7147.74 5042.75 8 6969.71 E 5969182.87 N 378610.50 E 0.793 7738.39 12708.19 92.090 150.380 7091.11 7143.81 5125.24 S 7017.13 E 5969099.58 N 378656.50 E 0.824 7833.50 12803.54 91.660 149.370 7087.99 7140.69 5207.67 8 7064.96 E 5969016.35 N 378702.91 E 1.151 7928.74 12899.40 90.620 149.910 7086.08 7138.78 5290.36 8 7113.40 E 5968932.84 N 378749.93 E 1 .222 8024.52 12991.26 90.250 150.610 7085.38 7138.08 5370.128 7158.97 E 5968852.31 N 378794.13 E 0.862 8116.34 13085.39 89.690 150.300 7085.43 7138.13 5452.01 8 7205.38 E 5968769.64 N 378839.13 E 0.680 8210.44 13182.10 89.940 150.450 7085.74 7138.44 5536.08 S 7253.19 E 5968684.77 N 378885.50 E 0.301 8307.12 13280.91 90.250 150.850 7085.58 7138.28 5622.20 S 7301.62 E 5968597.83 N 3·78932.45 E 0.512 8405.91 13323.65 90.180 151.160 7085.42 7138.12 5659.59 S 7322.34 E 5968560.09 N 378952.52 E 0.744 8448.65 13402.00 90.180 151 . 160 7085.17 7137.87 5728.22 S 7360.13 E 5968490.83 N 378989.13 E 0.000 8526.99 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 52.70' MSL. Northings and Eastings are relative to 2013' FNL, 1509' FEL. Global Northings and Eastings are relative to NAD27 Alaska 8tate Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical 8ection is from 2013' FNL, 1509' FEL and calculated along an Azimuth of 151.790° (True). Magnetic Declination at Surface is 24.741°(20-Dec-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 13402.0Oft., The Bottom Hole Displacement is 9326.52ft., in the Direction of 127.893° (True). .---- ~. - . Sperry-Sun Drilling Services Survey Report for Alpine CD-2 . CD2-45 Your Ref: API 501032039500 Job No. AKZZ22201, Surveyed: 3 January, 2003 North Slope, Alaska Alaska North Slope Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment ,.-.. 13402.00 7137.87 5728.22 S 7360.13 E Projected Survey Survey tool program for CD2-45 Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 0.00 13402.00 7137.87 AK-6 BP _IFR-AK ,-,. _____~___ __~____.___ _0_0____-_-- 8 January, 2003 - 14:06 Page 70f7 DriflQuest 3.03.02.004 ) AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD2-45 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 'MD 'MD 13,402.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment( s) c51D/-Ö))~ 09-Jan-03 RECEIVED JAN 1 5 2003 Afasfœ Oil & Gas Cons. Commiaaion Anchcnge ~ ~ ~ Sperry-Sun Drilling Services ..--' Alaska North Slope North Slope, Alaska Alpine CD-2 CD2-45 MWD Job No. A KMW2220 1 , Surveyed: 3 January, 2003 Survey Report 8 January, 2003 ,~. Your Ref: API 501032039500 Surface Coordinates: 5974344.11 N, 371728.07 E (70020'17.3042" N, 151002' 27.0046" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 974344.11 N, 128271.93 W (Grid) Surface Coordinates relative to Structure: 98.60 S, 12.27 E (True) Kelly Bushing: 52.70ft above Mean Sea Level Elevation relative to Project V Reference: 52.70ft Elevation relative to Structure: 52.70ft spe""''-'V-5UI! DRILLING seRVices A Halliburton Company Survey Ref: 5vy10034 Sperry-Sun Drilling Services Survey Report for Alpine CD-2 - CD2-45 MWD Your Ref: API 501032039500 Job No. AKMW22201. Surveyed: 3 January, 2003 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) . (ft) (ft) (ft) (ft) (O/100ft) 0.00 0.000 0.000 -52.70 0.00 0.00 N 0.00 E 5974344.11 N 371728.07 E 0.00 MWD M8çjnetic 114.00 0.000 0.000 61.30 114.00 0.00 N 0.00 E 5974344.11 N 371728.07 E 0.000 0.00 210.69 0.430 334.430 157.99 210.69 0.33 N 0.16W 5974344.44 N 371727.92 E 0.445 -0.36 302.76 1.230 88.180 250.05 302.75 0.67 N 0.68 E 5974344.77 N 371728.76 E 1.583 -0.25 ~. 395.03 3.810 101.860 342.23 394.93 0.07 N 4.67 E 5974344.10 N 371732.74 E 2.851 2.22 486.69 6.450 107.480 433.51 486.21 2.10 S 12.57 E 5974341.79 N 371740.60 E 2.928 7.97 575.76 9.870 115.490 521.67 574.37 6.89 S 24.23 E 5974336.81 N 371752.18 E 4.037 17.84 663.64 13.350 120.000 607.74 660.44 15.21 S 39.82 E 5974328.22 N 371767.63 E 4.089 32.71 752.78 13.860 121.430 694.38 747.08 25.92 S 57.84 E 5974317.20 N 371785.46 E 0.685 50.85 844.99 13.650 121.370 783.94 836.64 37.34 S 76.56 E 5974305.46 N 371803.98 E 0.228 69.96 935.29 12.900 119.700 871.83 924.53 47.88 S 94.41 E 5974294.62 N 371821.65 E 0.933 87.87 1028.10 14.900 119.790 961.92 1014.62 58.95 S 113.77 E 5974283.23 N 371840.81 E 2.155 106.97 1123.15 18.230 120.210 1053.01 1105.71 72.50 S 137.23 E 5974269.27 N 371864.04 E 3.506 130.25 1217.47 21.090 119.470 1141.82 1194.52 88.28 S 164.76 E 5974253.03 N 371891.29 E 3.044 157.46 1312.61 21.790 113.780 1230.39 1283.09 103.82 S 195.82 E 5974236.95 N 371922.09 E 2.306 186.18 1407.46 25.000 117.380 1317.43 1370.13 120.14 S 229.74 E 5974220.06 N 371955.72 E 3.703 216.98 1502.11 28.780 118.440 1401.84 1454.54 140.20 S 267.55 E 5974199.35 N 371993.18 E 4.026 252.94 1597.72 31 .690 116.560 1484.43 1537.13 162.39 S 310.26 E 5974176.43 N 372035.51 E 3.200 293.15 1696.57 33.240 115.410 1567.83 1620.53 185.63 S 357.96 E 5974152.38 N 372082.80 E 1.688 336.71 1791.32 36.990 113.840 1645.33 1698.03 208.30 S 407.51 E 5974128.87 N 372131.95 E 4.071 380.68 1887.55 41.610 113.300 1719.77 1772.4 7 232.65 S 463.36 E 5974103.56 N 372187.38 E 4.814 429.20 ..-. 1982.43 44.540 112.380 1789.07 1841 .77 257.79 S 523.08 E 5974077.41 N 372246.66 E 3.158 480.28 2077.63 45.940 112.940 1856.10 1908.80 283.84 S 585.45 E 5974050.30 N 372308.58 E 1.529 533.45 2173.15 46.890 112.680 1921.96 1974.66 310.66 S 649.23 E 5974022.39 N 372371.89 E 1.014 587.99 2269.17 46.540 113.010 1987.79 2040.49 337.79 S 713.65 E 5973994.16 N 372435.84 E 0.442 643.11 2363.85 47.460 112.070 2052.36 2105.06 364.33 S 777.60 E 5973966.53 N 372499.33 E 1.213 697.48 2459.15 46.840 112.410 2117.17 2169.87 390.78 S 842.27 E 5973938.98 N 372563.53 E 0.701 752.12 2554.23 46.010 112.860 2182.71 2235.41 417.28 S 905.85 E 5973911.39 N 372626.65 E 0.938 806.29 2649.22 45.360 113.720 2249.07 2301.77 444.15 S 968.28 E 5973883.46 N 372688.61 E 0.942 860.21 2721.06 45.690 113.250 2299.40 2352.10 464.58 S 1015.29 E 5973862.23 N 372735.27 E 0.655 900.98 2824.50 45.510 113.600 2371.78 2424.48 493.96 S 1083.11 E 5973831.69 N 372802.57 E 0.298 959.72 2920.21 45.690 113.150 2438.74 2491.44 521.09 S 1145.88 E 5973803.49 N 372864.86 E 0.385 1014.03 3013.72 45.240 113.080 2504.33 2557.03 547.26 S 1207.18 E 5973776.28 N 372925.71 E 0.484 1066.79 311 0.86 45.250 112.180 2572.72 2625.42 573.80 S 1270.85 E 5973748.65 N 372988.92 E 0.658 1121.03 3206.29 44.840 112.130 2640.15 2692.85 599.27 S 1333.40 E 5973722.12 N 373051.02 E 0.431 1173.78 ---~-- . - . ----- - 8 January, 2003 - 14:08 Page 20f7 Drif/Quest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for Alpine CD-2 - CD2-45 MWD Your Ref: API 501032039500 Job No. AKMW22201, Surveyed: 3 January, 2003 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 3301.68 44.730 112.890 2707.85 2760.55 624.99 8 1395.47 E 5973695.34 N 373112.65 E 0.573 1226.53 3397.43 44.800 112.080 2775.83 2828.53 650.788 1457.77 E 5973668.49 N 373174.50 E 0.600 1279.44 3491.75 44.760 111 .430 2842.78 2895.48 675.41 8 1519.48E 5973642.81 N 373235.77 E 0.487 1331.04 3588.86 44.820 111.760 2911.70 2964.40 700.58 8 1583.09 E 5973616.55 N 373298.95 E 0.247 1384.06 --. 3684.40 44.580 110.930 2979.61 3032.31 725.05 8 1645.68 E 5973591.02 N 373361.11 E 0.661 1435.96 3777.66 44.070 111.540 3046.33 3099.03 748.658 1706.42 E 5973566.38 N 373421.43 E 0.713 1486.20 3873.65 43.600 112.240 3115.57 3168.27 773.43 8 1768.11 E 5973540.55 N 373482.69 E 0.703 1537.94 3965.15 44.970 108.070 3181.09 3233.79 795.41 8 1828.07 E 5973517.55 N 373542.26 E 3.516 1586.38 4062.56 44.960 108.850 3250.01 3302.71 817.208 1893.36 E 5973494.64 N 373607.17 E 0.566 1637.27 4161 .35 44.81 0 108.070 3320.00 3372.70 839.28 8 1959.49 E 5973471.44 N 373672.91 E 0.577 1688.80 4257.02 44.500 107.430 3388.06 3440.76 859.788 2023.52 E 5973449.84 N 373736.59 E 0.571 1737.95 4351.77 45.110 111 . 1 50 3455.30 3508.00 881.848 2086.52 E 5973426.71 N 373799.20 E 2.840 1787.95 4447.99 44.780 110.120 3523.40 3576.10 905.79 S 2150.13 E 5973401.67 N 373862.39 E 0.830 1839.90 4542.29 45.350 110.590 3590.00 3642.70 929.01 8 2212.72 E 5973377.38 N 373924.57 E 0.700 1890.71 4639.32 45.210 110.040 3658.28 3710.98 952.95 8 2277.37 E 5973352.34 N 373988.81 E 0.428 1943.15 4734.74 44.980 110.220 3725.64 3778.34 976.21 8 2340.83 E 5973328.00 N 374051.85 E 0.276 1994.42 4828.71 44.840 109.560 3792.19 3844.89 998.78 8 2403.21 E 5973304.37 N 374113.84 E 0.518 2044.57 4925.97 44.940 108.050 3861.10 3913.80 1020.90 8 2468.18 E 5973281.13 N 374178.43 E 1.100 2095.59 5021.47 44.600 109.350 3928.90 3981.60 1042.47 8 2531.89 E 5973258.49 N 374241.76 E 1.023 2145.49 5116.64 44.160 109.710 3996.92 4049.62 1064.728 2594.62 E 5973235.17 N 374304.10 E 0.533 2195.53 5210.27 43.920 109.010 4064.23 4116.93 1086.29 8 2656.03 E 5973212.54 N 374365.13 E 0.579 2244.33 .- 5307.11 43.410 108.570 4134.28 4186.98 1107.838 2719.33 E 5973189.92 N 374428.05 E 0.613 2294.02 5400.63 44.230 111.380 4201.76 4254.46 1129.968 2780.17 E 5973166.76 N 374488.50 E 2.257 2343.02 5498.39 45.480 113.800 4271.07 4323.77 1156.458 2843.81 E 5973139.18 N 374551.68 E 2.164 2397.21 5592.29 45.300 113.000 4337.01 4389.71 1183.00 8 2905.16 E 5973111.58 N 374612.57 E 0.636 2450.32 5689.63 44.980 112.720 4405.67 4458.37 1209.81 8 2968.74 E 5973083.70 N 374675.68 E 0.387 2504.74 5785.29 45.650 114.240 4472.94 4525.64 1236.91 8 3031 .11 E 5973055.53 N 374737.58 E 1.329 2558.84 5880.90 45.470 114.610 4539.88 4592.58 1265.148 3093.27 E 5973026.25 N 374799.24 E 0.334 2613.81 5976.33 45.450 114.470 4606.82 4659.52 1293.39 8 3155.14 E 5972996.94 N 374860.63 E 0.107 2668.66 6071.92 45.490 114.610 4673.86 4726.56 1321.698 3217.13E 5972967.58 N 374922.12 E 0.112 2723.62 6166.52 45.280 113.010 4740.30 4793.00 1348.87 8 3278.74 E 5972939.35 N 374983.25 E 1.224 2777.41 6262.40 45.000 115.860 4807.94 4860.64 1376.98 8 3340.60 E 5972910.19 N 375044.63 E 2.127 2832.13 6357.80 45.110 113.870 4875.33 4928.03 1405.378 3401.86 E 5972880.76 N 375105.39 E 1.481 2886.80 6453.16 44.910 112.320 4942.75 4995.45 1431.82 S 3463.89 E 5972853.25 N 375166.96 E 1.169 2940.17 6549.14 44.630 112.880 5010.89 5063.59 1457.80 S 3526.29 E 5972826.21 N 375228.91 E 0.504 2993.29 ------~- - - - - ~,------- -------~- 8 January, 2003 - 14:08 Page 3 of7 DríllQl1est 3.03.02.004 Sperry-Sun Drilling Services Survey Report for Alpine CD·2 - CD2-45 MWD Your Ref: AP/501032039500 Job No. AKMW22201, Surveyed: 3 January, 2003 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 6644.69 44.820 112.170 5078.78 5131.48 1483.55 S 3588.40 E 5972799.39 N 375290.57 E 0.559 3046.08 6740.60 44.350 112.940 5147.09 5199.79 1509.37 S 3650.58 E 5972772.51 N 375352.29 E 0.747 3098.96 6836.00 43.740 113.060 5215.66 5268.36 1535.29 S 3711.63 E 5972745.55 N 375412.89 E 0.645 3151.38 6931.58 43.190 113.150 5285.03 5337.73 1561.09 S 3772.11 E 5972718.72 N 375472.92 E 0.579 3203.41 ~ 7027.09 42.610 112.610 5355.00 5407.70 1586.37 S 3832.01 E 5972692.42 N 375532.38 E 0.719 3254.71 7122.78 42.300 112.710 5425.60 5478.30 1611 .25 S 3891.61 E 5972666.52 N 375591.55 E 0.332 3305.52 7218.29 43.570 111.700 5495.52 5548.22 1635.83 S 3951.84 E 5972640.91 N 375651.35 E 1.512 3356.36 7313.51 42.910 112.750 5564.89 5617.59 1660.50 S 4012.23 E 5972615.22 N 375711.31 E 1.025 3407.36 7408.48 44.390 113.190 5633.61 5686.31 1686.09 S 4072.58 E 5972588.60 N 375771.21 E 1.591 3459.15 7503.94 44.250 112.280 5701.91 5754.61 1711.86 S 4134.09 E 5972561.78 N 375832.27 E 0.682 3511.66 7599.60 44.940 112.050 5770.02 5822.72 1737.20 S 4196.29 E 5972535.38 N 375894.03 E 0.741 3564.13 7695.16 46.350 111.790 5836.83 5889.53 1762.71 S 4259.68 E 5972508.80 N 375956.97 E 1.488 3617.33 7790.55 45.610 111 .170 5903.12 5955.82 1787.83 S 4323.51 E 5972482.59 N 376020.36 E 0.906 3670.40 7886.36 46.310 110.990 5969.72 6022.42 1812.60 S 4387.77 E 5972456.72 N 376084.19 E 0.743 3723.39 7982.02 45.420 110.560 6036.33 6089.03 1836.95 S 4451.96 E 5972431.27 N 376147.95 E 0.985 3775.97 8076.94 46.040 111.200 6102.59 6155.29 1861.18 S 4515.46 E 5972405.96 N 376211.03 E 0.812 3828.10 8172.19 45.390 110.730 6169.09 6221.79 1885.57 S 4579.13 E 5972380.48 N 376274.28 E 0.768 3880.4 7 8266.16 44.660 110.950 6235.51 6288.21 1909.22 S 4641.26 E 5972355.77 N 376335.99 E 0.794 3931.43 8363.50 44.190 110.430 6305.03 6357.73 1933.30 S 4705.00 E 5972330.61 N 376399.31 E 0.611 3983.55 8459.15 44.750 110.450 6373.29 6425.99 1956.70 S 4767.79 E 5972306.14 N 376461.69 E 0.586 4034.62 8554.26 44.120 110.910 6441.20 6493.90 1980.21 S 4830.08 E 5972281.57 N 376523.57 E 0.744 4085.54 ..- 8648.51 43.480 111.210 6509.22 6561.92 2003.65 S 4890.96 E 5972257.09 N 376584.04 E 0.714 4135.71 8745.37 43.260 110.530 6579.64 6632.34 2027.35 S 4953.11 E 5972232.33 N 376645.78 E 0.533 4186.72 8840.95 42.820 110.960 6649.49 6702.19 2050.45 S 5014.12 E 5972208.19 N 376706.38 E 0.553 4236.66 8872.28 42.910 111.000 6672.46 6725.16 2058.08 S 5034.02 E 5972200.21 N 376726.14 E 0.300 4253.03 8903.98 44.070 113.430 6695.46 6748.16 2066.34 S 5054.21 E 5972191.62 N 376746.19 E 6.420 4270.09 8935.87 45.330 117.000 6718.13 6770.83 2075.90 S 5074.49 E 5972181.71 N 376766.31 E 8.809 4288.33 8967.35 47.400 119.400 6739.85 6792.55 2086.67 S 5094.56 E 5972170.60 N 376786.19 E 8.583 4307.53 8999.05 48.870 121.530 6761.01 6813.71 2098.64 S 5114.91 E 5972158.28 N 376806.33 E 6.822 4327.90 9031.23 49.940 124.870 6781.95 6834.65 2112.02 S 5135.34 E 5972144.55 N 376826.53 E 8.553 4349.56 9062.08 50.950 125.810 6801.60 6854.30 2125.78 S 5154.74 E 5972130.46 N 376845.70 E 4.030 4371.04 9094.28 51.280 126.110 6821.81 6874.51 2140.50 S 5175.03 E 5972115.40 N 376865.73 E 1.255 4393.78 9126.72 52.420 127.780 6841.85 6894.55 2155.83 S 5195.42 E 5972099.72 N 376885.85 E 5.361 4417.12 9156.45 53.690 129.150 6859.72 6912.42 2170.61 S 5214.02 E 5972084.62 N 376904.20 E 5.640 4439.09 9188.51 54.760 130.120 6878.46 6931 .16 2187.21 S 5234.05 E 5972067.69 N 376923.94 E 4.143 4463.35 -~---- - - - 8 January, 2003 - 14:08 Page 4 0£7 DrillQ/lest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for Alpine CD-2 - CD2-45 MWD Your Ref: API 501032039500 Job No. AKMW22201, Surveyed: 3 January, 2003 Nortl} Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9222.36 56.200 131.970 6897.64 6950.34 2205.52 S 5255.08 E 5972049.02 N 376944.65 E 6.194 4489.60 9252.88 57.890 133.070 6914.25 6966.95 2222.83 S 5273.95 E 5972031.39 N 376963.23 E 6.309 4513.92 9285.46 59.530 133.400 6931.17 6983.87 2241.90 S 5294.23 E 5972011.97 N 376983.18 E 5.108 4540.46 9315.38 61.220 136.340 6945.96 6998.66 2260.25 S 5312.66 E 5971993.31 N 377001.29 E 10.240 4565.4 7 ....-. 9349.02 62.620 137.920 6961.79 7014.49 2282.00 S 5332.85 E 5971971.22 N 377021.10 E 5.873 4594.31 9380.92 63.490 136.560 6976.25 7028.95 2302.88 S 5352.16 E 5971950.01 N 377040.05 E 4.678 4621.95 9413.23 63.960 138.610 6990.55 7043.25 2324.27 S 5371.69 E 5971928.29 N 377059.22 E 5.872 4650.16 9445.70 65.370 138.580 7004.45 7057.15 2346.28 S 5391.10 E 5971905.95 N 377078.25 E 4.343 4678.84 9476.04 66.470 140.390 7016.83 7069.53 2367.34 S 5409.10 E 5971884.59 N 377095.88 E 6.543 4706.00 9508.79 67.250 141.610 7029.70 7082.40 2390.74 S 5428.05 E 5971860.87 N 377114.43 E 4.172 4735.68 9538.52 68.500 143.320 7040.89 7093.59 2412.58 S 5444.82 E 5971838.74 N 377130.83 E 6.787 4762.93 9571.98 70.300 144.070 7052.67 7105.37 2437.82 S 5463.37 E 5971813.19 N 377148.93 E 5.774 4794.01 9599.32 71.950 143.900 7061.51 7114.21 2458.74 S 5478.58 E 5971792.01 N 377163.78 E 6.064 4819.69 9641.81 74.320 147.290 7073.84 7126.54 2492.29 S 5501.54 E 5971758.08 N 377186.17 E 9.455 4860.18 9672.96 76.350 146.070 7081.73 7134.43 2517.47 S 5518.09 E 5971732.62 N 377202.29 E 7.538 4890.23 9699.37 77.350 149.050 7087.74 7140.44 2539.17 S 5531.89 E 5971710.68 N 377215.71 E 11 .622 4915.91 9730.84 78.240 148.700 7094.39 7147.09 2565.50 S 5547.79 E 5971684.08 N 377231 .16 E 3.030 4946.65 9762.96 79.670 148.090 7100.54 7153.24 2592.35 S 5564.31 E 5971656.96 N 377247.22 E 4.826 4978.15 9794.87 81.780 149.670 7105.69 7158.39 2619.31 S 5580.58 E 5971629.72 N 377263.03 E 8.222 5009.62 9828.64 83.840 151.560 7109.91 7162.61 2648.50 S 5597.02 E 5971600.26 N 377278.96 E 8.249 5043.12 9858.24 86.130 150.480 7112.50 7165.20 2674.29 S 5611.30 E 5971574.22 N 377292.81 E 8.548 5072.60 ~ 9890.49 88.640 150.990 7113.97 7166.67 2702.39 S 5627.05 E 5971545.85 N 377308.07 E 7.942 5104.82 9908.02 89.600 151.560 7114.24 7166.94 2717.76 S 5635.47 E 5971530.34 N 377316.23 E 6.369 5122.34 10038.11 90.920 149.310 7113.65 7166.35 2830.90 S 5699.66 E 5971416.12 N 377378.47 E 2.005 5252.42 10128.14 89.320 151.330 7113.46 7166.16 2909.12 S 5744.23 E 5971337.16 N 377421.70 E 2.862 5342.44 10227.59 88.890 151.350 7115.02 7167.72 2996.37 S 5791.92 E 5971249.10 N 377467.89 E 0.433 5441.87 10322.71 89.260 149.500 7116.55 7169.25 3079.08 S 5838.86 E 5971165.60 N 377513.41 E 1.983 5536.97 10418.57 89.750 150.470 7117.38 7170.08 3162.08 S 5886.81 E 5971081.79 N 377559.93 E 1.134 5632.82 10510.34 89.940 151.150 7117.63 7170.33 3242.20 S 5931.57 E 5971000.92 N 377603.31 E 0.769 5724.59 10605.21 90.310 150.470 7117.42 7170.12 3325.02 S 5977.84 E 5970917.32 N 377648.15 E 0.816 5819.46 10699.01 90.250 150.330 7116.96 7169.66 3406.58 S 6024.17 E 5970834.98 N 377693.08 E 0.162 5913.25 10799.05 90.060 149.980 7116.69 7169.39 3493.35 S 6073.95 E 5970747.37 N 377741.38 E 0.398 6013.29 10894.66 90.000 149.830 7116.64 7169.34 3576.07 S 6121.89 E 5970663.84 N 377787.90 E 0.169 6108.88 10990.40 89.450 149.330 7117.10 7169.80 3658.63 S 6170.37 E 5970580.46 N 377834.95 E 0.776 6204.GO 11085.48 89.880 150.460 7117.66 7170.36 3740.88 S 6218.06 E 5970497.41 N 377881.23 E 1.272 6299.67 -----~._----- -- 8 January, 2003 - 14:08 Page 50f7 DrillQuest 3.03.02.004 Dri/lQllest 3.03.02.004 Page 60f7 8 January, 2003 - 14:08 _____ ___n_______ ----~._- ---_..~ Sperry-Sun Drilling Services Survey Report for Alpine CD-2 - CD2-45 MWD Your Ref: API 501032039500 Job No. AKMW22201, Surveyed: 3 January, 2003 North Slope, Alaska Alaska North Slope Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 11181.10 90.120 152.960 7117.66 7170.36 3825.07 S 6263.37 E 5970412.45 N 377925.09 E 2.627 6395.27 11276.75 90.550 153.530 7117.10 7169.80 3910.48 S 6306.43 E 5970326.32 N 377966.69 E 0.746 6490.83 11372.08 90.310 152.600 7116.38 7169.08 3995.47 S 6349.61 E 5970240.61 N 378008.41 E 1.007 6586.08 11467.59 91.110 153.850 7115.20 7167.90 4080.73 S 6392.63 E 5970154.63 N 378049.96 E 1.554 6681.49 11559.82 90.490 153.370 7113.91 7166.61 4163.34 S 6433.62 E 5970071.33 N 378089.53 E 0.850 6773.60 11655.58 90.060 153.180 7113.45 7166.15 4248.87 S 6476.69 E 5969985.07 N 378131.13 E 0.491 6869.27 11749.14 90.680 152.960 7112.85 7165.55 4332.28 S 6519.06 E 5969900.95 N 378172.07 E 0.703 6962.75 11846.15 89.820 151.720 7112.42 7165.12 4418.20 S 6564.09 E 5969814.27 N 378215.62 E 1.556 7059.72 11940.17 89.940 152.600 7112.62 7165.32 4501.34 S 6608.00 E 5969730.40 N 378258.10 E 0.945 7153.71 12035.68 90.000 151.740 7112.67 7165.37 4585.80 S 6652.59 E 5969645.18 N 378301.24 E 0.903 7249.20 12131.64 91.600 151.950 7111.33 7164.03 4670.39 S 6697.86 E 5969559.83 N 378345.06 E 1.682 7345.13 12227.88 92.150 150.140 7108.18 7160.88 4754.55 S 6744.43 E 5969474.88 N 378390.18 E 1.965 7441.31 12326.62 90.920 149.770 7105.54 7158.24 4839.99 S 6793.84 E 5969388.61 N 378438.13 E 1.301 7540.00 12422.20 91.540 149.440 7103.48 7156.18 4922.42 S 6842.19 E 5969305.37 N 378485.06 E 0.735 7635.54 12517.63 92.960 149.510 7099.74 7152.44 5004.56 S 6890.62 E 5969222.41 N 378532.08 E 1 .490 7730.87 12612.96 92.650 149.860 7095.07 7147.77 5086.758 6938.69 E 5969139.41 N 378578.72 E 0.490 7826.07 12708.19 92.090 150.200 7091.14 7143.84 5169.188 6986.22 E 5969056.18 N 378624.84 E 0.688 7921.21 12803.54 91 .660 149.790 7088.02 7140.72 5251.708 7033.87 E 5968972.85 N 378671.08 E 0.623 8016.50 12899.40 90.620 149.970 7086.11 7138.81 5334.60 S 7081.97 E 5968889.14 N 378717.74 E 1.101 8112.32 12991.26 90.250 151.310 7085.41 7138.11 5414.66 S 7127.00 E 5968808.33 N 378761.40 E 1.513 8204.18 13085.39 89.690 150.660 7085.46 7138.16 5496.98 S 7172.66 E 5968725.24 N 378805.65 E 0.911 8298.31 13182.10 89.940 153.100 7085.77 7138.47 5582.26 S 7218.24 E 5968639.19 N 378849.76 E 2.536 8394.99 13280.91 90.250 153.300 7085.61 7138.31 5670.46 8 7262.79 E 5968550.24 N 378892.79 E 0.373 8493.71 13323.65 90.180 152.310 7085.45 7138.15 5708.4 7 S 7282.32 E 5968511.90 N 378911.67 E 2.322 8536.43 13402.00 90.180 152.310 7085.20 7137.90 5777.85 S 7318.73 E 5968441.91 N 378946.89 E 0.000 8614.75 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 52.70' MSL. Northings and Eastings are relative to 2013' FNL, 1509' FEL. Global Northings and Eastings are relative to NAD27 Alaska 8tate Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 2013' FNL, 1509' FEL and calculated along an Azimuth of 150.790° (True). Magnetic Declination at Surface is 24.72r(03-Jan-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 13402.00ft., The Bottom Hole Displacement is 9324.56ft., in the Direction of 128.290° (True). ----. ~ Sperry-Sun Drilling Services Survey Report for A/pine CD-2 - CD2-45 MWD Your Ref: AP/501032039500 Job No. AKMW22201, Surveyed: 3 January, 2003 North Slope, Alaska Alaska North Slope Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment ~ 13402.00 7137.90 5777.85 S 7318.73 E Projected Survey Survey tool program for CD2-45 MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 0.00 13402.00 7137.90 MWD Magnetic ,~ ---------- ------ --- - -- - . ---~--- - -- --- 8 January, 2003 - 14:08 Page 70f7 DrillQuest 3.03.02.004 ) ) Randy Thomas dO / -;} J~ Greater Kuparuk Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 RL Thomas@ppco.com Conoc~hillips January 10, 2003 Cammy Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Annular Disposal, Fourth Quarter, 2002 Dear Commissioner: Please find attached the fourth quarter 2002 annular disposal for the Kuparuk, Alpine and Cook Inlet Fields. This report shows the volumes disposed into surface casing by production casing annuli during the fourth quarter of 2002, as well as total volumes disposed into annuli for which disposal authorization expired during the fourth quarter of 2002. Please call me at 265-6830 should you have any questions. Sincerely, -,-'""":::> ~ \~'~ R. Thomas Greater Kuparuk Team Leader RT/skad cc: Marty Lemon Mike Mooney Paul Mazzolini Chip Alvord Kuparuk Environmental B. Morrison I R. Overstreet Sharon Allsup-Drake Well Files RECE1VED A ¡::' ()OOj'" .\I~N \ J L Alaska Oil & Gas Cons. Commission Anchorëg8 Annular Disposal during the fourth quarter of 2002: h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes CD2-26 15244 100 0 15344 380 13902 29626 September October CD2-38, CD2-44, CD2-29, 2002 2002 CD2-13 CD2-34 22895 100 0 22995 372 0 23367 Oct 2002 Dec 2002 CD2-13, CD2-37, CD2-35 CD2-48 11281 100 0 11381 375 0 11756 Dec 2002 Dec 2002 CD2- 28, CD2-45 3S-07 18155 100 0 18255 216 0 18471 Dec 2002 Dec 2002 3S-09,3S-14,3S~10 3S-18 206 100 0 306 0 0 306 Dec 2002 Dec 2002 3S-18 \ Total Volumes into Annulifor which Disposal Authorization Expired during the fourth quarter 2002: Freeze Protect Total Volume Start End Source Wells Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus CD2-39 29466 100 0 379 29945 Open, Freeze· Protected October Sept 2002 CD2-15, CD2-47, CD2- 2001 44 CD2-14 30597 100 0 376 31073 Open, Freeze Protected November March CD2-45, CD2-47, CD2- 2001 2002 32, lC-14 32115 100 0 0 32215 Open, Freeze Protected October January 1C-109, 1R-36, 1C-24 2001 2002 2P-438 30331 100 0 212 30643 Open, Freeze Protected October December 2P-420, 2P-415, 2P-429 2001 2001 CD2-15 31181 100 0 371 31652 Open, Freeze Protected March 2002 September CD2-50, CD2-25, CD2- 2002 44 \ ) CD2-47 26874 100 0 375 27349 Open, Freeze Protected December January CD2-34, CD2-26 2001 2002 CD2-45 22514 100 0 377 22991 Open, Freeze Protected January February CD2-49, CD2-17 2002 2002 Cook Inlet Annular Disposal during the fourth quarter 2002: h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes Hansen #1 472 100 0 572 0 67224 67796 January October Hansen # 1 2002 2002 ) ') ..~ ConocoPhillips Jt Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 December 11 , 2002 Alaska Oil and Gas Conservation Commission 333 West J'h Avenue, Suite 100 Anchorage, Alaska, 99501 :tV t ~ 2- I '2... Re: Application for Sundry Approval- Resumption of Drilling Operations CD2·45 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for Sundry Approval to resume drilling operations on well CD2M45 with Doyon rig 19, at Alpine. Drilling will be resumed on CD2-45 on approximately December 30, 2002. It is intended to move the rig back to CD2M45 in order to drill the production interval with mineral oil based mud. In November 2001 severe losses were encountered on CD2-45 shortly after drilling ahead with oil based mud. The losses are thought to be caused by faulting and low reservoir pressure in the Alpine. Reservoir pressure has since been increased in that area. Please find attached Form 10-403, Application for Sundry Approvals, and the proposed program for drilling the well. If you have any questions or require further information, please contact Vern Johnson at 265-6081 or Chip Alvord at 265M6120. ~~~7~ Vern Johnson Drilling Engineer r02-/0L.- Attachments cc: CD2-45 Well File / Sharon Allsup Drake Chip Alvord Cliff Crabtree Meg Kremer Nancy Lambert Lanston Chin ATO 1530 ATO 868 ATO 848 ATO 844 Anadarko - Houston Kuukpik Corporation e-mail : Tommy_Thompson @ anadarko.com RECEIVED DEC 1 3 2002 Alaska Oil & Gas Cons. (;OIllfHSSlon Anchorage " '"". : ) ) 1/'-'61\- I 2-11 ~ I /) 2-~ ~ '~I? {'ZJ;lø'Z.- ¡Vt-£..6 12./ f3 /0 z... CoT , '2--f( ~)/~"'- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS J 1. Type of request: Abandon Suspend _ Alter casing _ Repair well _ Change approved program _ 2. Name of Operator ConocoPhillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2013' FNL, 1509' FEL, Sec. 2, T11 N, R4E, UM At top of productive interval 612' FSL, 1098' FEL, Sec. 1, T11N, R4E, UM At effective depth At total depth 2043' FNL, 316' FWL, Sec. 7, T11 N, R5E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10038 7160 10038 7160 Casing Conductor Surface Production Length 77' 2727' 9935' Size 16" 9.625" 7" Perforation depth: measured None true vertical None Operational shutdown _ Plugging _ Pull tubing _ 5. Type of Well: Development _X Exploratory _ Stratigraphic _ Service (as proposed) (as proposed) feet Plugs (measured) feet feet Junk (measured) feet Cemented 270 sx AS 1 389 sx AS IIIL, 237 sx Class G 165 sx Class G Tubing (size, grade, and measured depth) 4.5", 12.6#, L-80 @ +/-2525' MD Packers & SSSV (type & measured depth) Bridge plug @ 5334 13. Attachments Description summary of proposal _ 14. Estimated date for commencing operation December 30, 2002 16. If proposal was verbally approved Re-enter suspended well _XX Time extension Stimulate Variance Perforate 6. Datum elevation (OF or KB feet) RKB 36' / 52.7' AMSL 7. Unit or Property name Other Colville River Unit 8. Well number /' CD2-45 9. Permit number / approval number 201-212 ,/,. 10. API number 50-103-20395-00 11. Field / Pool Colville River Field/Alpine Oil Pool Measured Depth 114' 2764' 9972' True vertical Depth 114' 2389' 7167' RECEIVED DEC 1 3 2002 Nas1å1 Oil & Gas Gons. Commission Anchorage Detailed operations program _ 15. Status of well classification as: BOP sketch Oil Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so represen~Jve may witness I Approval no. _ ':J Plug integrity _ BOP Test]5. Location clearance - 1/" 3cv- -~[?y Mechanical Integrity Test _ Subsequent form required 10- T" 7 Te c;t- 1:$? PE. to 50 C' 0 () <; t . A tl C+~~ V" 0 ¡,-,¿,\,~ v~~.l f2.Rý'vvt-it c..:Çi pvt.l~t,¿~ ltfpt"l' Approved by order of the Commission. Commissi9A,er OkIGINAL SIGNI:U BY U~G 2 1 M L. Bill \- Signed Chip Alvord ~ (, Otf- Form 10-403 Rev 06/15/88 · Title: Alpine Drilling Team Leader Gas Suspended _XX Questions? Call Vern Johnson 265-6081 Date { 2-( (1...( ð L Prepared by Sharon Allsup-Drake Date ¡.;j; 9/62 I' " '¡OMS BFl SUBMIT IN TRIPLICATE ) ) CD2..45 Re-entrv Procedure: 1. Move in with rig Doyonl9. 2. Rig up on CD2-45 3. Remove BPV and install2-way check with lubricator. 4. Nipple down wellhead adapter assembly. 5. Install and test BOPE to 5000 psi / 6. Pull2-way check. 7. Displace diesel freeze protect with 9.6 ppg brine. 8. Pull tubing hanger and circulation string. 9. Pick up and run in hole with bridge plug retrieval assembly. 10. Tag bridge plug and displace brine with 8.6 ppg oil based mud. /' 11. Pull bridge plug, pull out of hole and lay down retrieval assembly. 12. Pick up and run the 6-1/8 drilling assembly (GR/Res/PWD/dir). 13. Drill 6-1/8" horizontal section to well TD at 12906' MD 17168' TVD. / 14. Circulate hole clean and Pull out of hole. /' 15. Run 4-1h, 12.6 #, L-80 tubing with 83 packer, mill-out extension, CMD sliding sleeve (closed), gas lift mandrels (all GLM's with dummy valves), Calnco BAL-O 888V nipple and dual control line. MID hanger and pressure test the control lines to 5000 psi. Land hanger, back out landing joint. Install 2- way check with rods. MID landing joint and test hanger seals to 5000 psi. /' 16. Nipple down BOP. 17. Install wellhead adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2-way check with lubricator. 18. Displace tubing and annulus to diesel by pumping diesel conventionally at 5 bpm. /' 19. Drop ball and rod and set packer. Test tubing to 3500 psi 130 min. Test casing annulus to 3500 psi I 30 mins. 20. Set BPV and secure well. Move rig off. Annular Disposal during the first quarter of 2002: h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes 2P-417 25534 100 0 25634 887 5431 31952 October March 2P-448, 2P-422A, Grizzly #1, 2001 2002 2P-451, 2P-441, 2P-420 CD2-14 16138 100 0 16238 376 14459 31073 November March CD2-32, CD2-47, CD2-45 2001 2002 lC-14 9626 100 0 9726 0 22489 32215 October January 1R-36, 1C-24, 1C-109 2001 2002 ( CD2-15 10346 100 0 10446 371 0 10817 March March CD2-50 2002 2002 CD2-47 16459 100 0 16559 375 10415 27349 December January CD2-34, CD2-26, 2001 2002 (3/)1 ~ d. J;). CD2-45 22514 100 0 22614 377 0 22991 January February CD2-49, CD2-17 2002 2002 2P-415A 4843 100 0 4943 52 0 4995 March March Grizzly #1, 2P-431, 2P-441 2002 2002 CD2-26 0 0 0 0 380 0 380 Freeze protect only for CD2- 26 CD2-49 0 0 0 0 386 0 386 Feb 2002 Feb 2002 Freeze protect only Total Volumes into Annulifor which Disposal Authorization Expired during the first quarter 2002: Freeze Protect Total Volume Start End Source Wells Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus Æ ID-32 23162 100 0 337 23599 Open, Freeze Protected January February ID-39 2001 2001 IJ -03 30024 100 0 0 30124 Open, Freeze Protected March 2001 May 2001 11-09, 11-14, 11-10 ) ) NOTE TO FILE PPCo CD2-45 201-212 301-345 Request for Annular Disposal Phillips has applied for approval to dispose of drilling waste via annular disposal in Colville River Unit well CD2-45. Cementing and LOT records were submitted for the subject well as well as surrounding wells. With regard to CD2-45 , the surface casing was set as planned, The casing was successfully cemented. The casing was reciprocated and 100 bbls of cement circulated. The volume of cement that remained in the wellbore was about 1.7 x gage hole. The casing successfully tested and the initial leakoff was determined to be about 16.0 ppg EMW. Remaining operations went well until the 7" was set. Lost circulation was experienced while breaking circulation to cement. The casing was cemented with an observed static fluid level about 20' down, but without returns. It is stated that a pumping pressure increase was noted when the cement "went around the corner". The subsequent leakoff pressure was determined to be 13.8 - 13.9 ppg EMW. The curve is well developed and based on the submitted information, CD2-45 appears to be satisfactorily constructed for purposes of annular disposal. PPCo has also submitted information regarding wells within a % mile radius of the surface casing shoe of CD2-47. At this time, 3 other wells were identified. The nearest well is CD2-39, 470' away. This well was permitted for annular disposal in October 2001. Nearly 28000 bbls of waste has been disposed into that annulus. The absolute values of the leakoffs are similar to CD2-45. PPCo has not reported any problems with disposal into CD2-39, The next closest well is CD2-35 some 481' distant. CD2-35 is a renamed exploration well that was drilled in early 1998. The surface casing on this well was. set slightly deeper than the current practice for CRU development wells. The initial LOT indicates the casing was satisfactorily cemented. CD2-35 has not been permitted for annular disposal. The final well, CD2-14, is 1250' distant. This well was also approved for annular disposal in October 2001. To date slightly more than 10000 bbls of waste has been pumped into this annulus. PPCo has not reported any problems with disposal into C02.. 14. I recommend approval of PPCo's request for annular disposal in CD2-47. h~~~ \J'<.c:::... \~ \d-~' Tom Maunder, PE Sr. Petroleum Engineer ) ') Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 December 11,2001 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Application for Sundry Approval for Annular Disposal of Drillin~ Waste on well CD2-45 Dear Sir or Madam: Phillips Alaska, Inc. hereby requests that CD2-45 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. The well is currently suspended with 7" casing landed in the Alpine interval. Doyon 19 will return to drill the 6-1/8" horizontal in approximately 8 weeks. It is intended to begin annular injection on CD2-45 approximately January 8, 2001. Please find attached form 10-403 and other pertinent information as follows: 1. Form 10-403 2. Annular Disposal Transmittal Form 3. Pressure Calculations for Annular Disposal 4. Surface Casing Description 5. Surface Casing Cementing Report & Daily Drilling Report during cement job 6. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 7. Intermediate Casing Description 8. Intermediate Casing Cementing Report & Daily Drilling Report during cement job 9. Formation LOT on 9-5/8" x 7" casing annulus 10. Plan View of Adjacent Wells 11. Details regarding wells within ~ mile radius of surface casing shoe. If you have any questions or require further information, please contact Vern Johnson at 265- 6081, or Chip Alvord at 265-6120. ~. Vern JO~S~ Drilling Engineer /2//,; ~ ( RECEIVED DEC 1 2 2001 cc: CD2-45 Well File Chip Alvord Nancy Lambert Sharon Allsup-Drake A TO-868 Anadarko ATO-1530 Alaska on & Gas Cons. Commission Anchofage OR\G\NAL ') ~ ðMW , vll't /0\ ~';> In ~~ yv /~ ~ _/' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon Suspend _ Alter casing _ Repair well _ Change approved program _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2013' FNL, 1509' FEL, Sec. 2, T11N, R4E, UM At top of productive interval 612' FSL, 1098'FEL,Sec. 1,T11N,R4E,UM At effective depth At total depth 2043' FNL, 316' FWL, Sec. 7, T11 N, R5E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: 10038 7160 10038 7160 measured true vertical Casing Conductor Surface Length 77' 2727' Size 16" 9-5/8" Production 9935' 7" Perforation depth: measured None true vertical None Operational shutdown _ Plugging _ Pull tubing _ 5. Type of Well: Development __X Exploratory _ Stratigraphic __ Service Re-enter suspended well _ Time extension Stimulate Variance Perforate 6. Datum elevation (DF or KB feet) FzKB ¿:¡2 feet 7. Unit or Property name Other _X Annular Disposal Colville River Unit 8. Well number CD2-45 9. Permit number / approval number 201-212 10. API number 50-103-20395-00 11. Field / Pool ----- Per APD Colville River Field I Alpine Oil Pool Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed CO;p AJ""'Þ- t. Qv( TItle: Alpine Drilling Team Leader ----- Per APD feet Plugs (measured) feet feet Junk (measured) feet Cemented 270 Sx AS1 389 Sx AS III L & 237 Sx 15.8 class G 165 Sx 15.8 class G ORIGINAL Measured Depth 114' 2764' True vertical Depth 114' 2389' 9972' 7167' RECEIVED DEC 1 2 2001 Tubing (size, grade, and measured depth Alaska Oil & Gas Cons. Comm;ssìon # @ ('" f') Anchorage 4.5" 12.6 ,L-80 +/-2525' MD circulation stnng or suspension . Packers & SSSV (type & measured depth) 13. Attachments Description summary of proposal __ Detailed operations program _ BOP sketch Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets, schematic __X 14. Estimated date for commencing operation 15. Status of well classification as: January 8, 2001 16. If proposal was verbally approved Oil _X Gas Suspended __ Questions? Call Vern Johnson 265-6081 Date (2-( (( 10 ( FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval no. ~, t21 \ c.... Plug integrity _ BOP Test Location clearance _ r vAJl' '..)'1- ) Mechanical Integrity Test _ Subsequent form required 10- C"t:.\?{\ \\ <J \- C). f\.~~ \0., ~\ ~'D~~~ \. Origina' Signed By , Approved by order of the Commission r.ammv Oechs\i Commissioner Date 1;:2 / / :3)0 I Form 10-403 Rev 06/15/88 . SUBMIT IN TRIPLICATE ) ) Annular Disposal Transmittal Form a. Designation of the well or wells to receive drilling wastes. C D2-45 b. The depth to the base of freshwater aquifers There are no USDW aquifers in the Colville and permafrost, if present. River Unit. Base of Permafrost = 1552' TVD (RKB) c. A stratigraphic description of the interval The Schrader Bluff formation provides an upper exposed to the open annulus and other barrier and marine shales and claystones of the information sufficient to support a commission Lower Cretaceous Torok Formation provide a finding that the waste will be confined and will lower barrier. Calculated water salinities of the not come to the surface or contaminate Cretaceous and older stratigraphic sections freshwater. range from 15000 to 18000 mg/I. (Ref. AOGCC Conservation Order No. 443, March 15,1999) d. A list of all publicly recorded wells within one- See attached map indicating wells within 1/4 quarter mile and all publicly recorded water mile. There are no water wells within 1 mile. wells within one mile of the well to receive drilling waste. e. Identify the types and maximum volume of waste to be disposed of and the estimated density of the waste slurry. f. An estimate of maximum anticipated pressure at the outer casing shoe during annular disposal operation and calculations showing how this value was determined. g. Details that show the shoe of the outer casing is set below the base of any freshwater aquifer and permafrost, if present, and cemented with sufficient cement to provide zone isolation. Types of fluids can be mud, diesel, cement, and water. Maximum volume to be pumped is 35,000 bbls. Maximum anticipated pressure at casing shoe during disposal operations is 1910 psi. See attached calculation page. See attached cementing reports, LOT/FIT reports, and casing reports. h. Details that show the inner and outer casing See attached casing summary sheet and strings have sufficient strength in collapse and calculation page. burst to withstand anticipated pressure of disposal operations. i. Any additional data required by the NA Commission to confirm containment of drilling wastes. ') ) CD2-45 Pressure Calculations for Annular Disposal èi3 03 "'C co "'C OJ co ..c: OJ ..c: ëñ ëñ 0. 0. 0 0 0 0> 0 0 c N 0 'ëj) N co + + Ü s:: it:: õo ëñ ëñ Lñ 0. 0. ~ ...... ...... 0 0 ~ (/) (/) co co (9 (9 ... , .... . ... .... .... ... Töë' Z Z 0) c: :ë :J I- 0) ~ ...... c: ..} 'ëi) co Ü ¡:.... ~ L ~ DET AILS: {::::9-5/8" 361b/ft, J-55 BTC casing @ 2764 ft MD (2389 ft TVD) Pburst = 3520 psi, @ 850/0: Pburst85% = 2992 psi Estimated Top of Cement @ 9010 ft MD (6814 ft TVD) (7" csg x 8-1/2" Open hole annulus) {::::4-1/2" 12.61b/ft L-80 tubing to 9423 ft MD (planned) {::::7" 26 Ib/ft, L-80, BTC casing @ 9972 ft MD (7167 ft TVD) Pcollapse = 5410 psi, @ 85°/Ó: Pcollapse85% = 4598 psi ASSUMPTIONS: · Maximum injection pressure, P Applied = 1500 psi · Maximum density of injection fluid is 12.0 ppg. · Pore pressure at 9-5/8" casing shoe is 0.4525 psi/ft · Injection gas pressure is 0.1 psi/ft + 2000 psi header pressure CALCULATIONS: Maximum pressure at 9-5/8" shoe: P max = PHydrostatic + P Applied - PFormation Pmax = 12.0 (0.052) (2389)+1500 - 0.4525 (2389) Pmax = 1910 psi Maximum fluid density to burst 9-5/8" casinç¡: Pburst85% = PHydrostatic + P Applied - PFormation 2992 = MWmax (0.052) (2389) + 1500- 0.4525 (2389) MWmax = 20.7 ppg Maximum Fluid Density to Collapse 7" Casing: P collapse85% = PHydrostatic + P Applied - P GasGradient - PHeader 4598 = MWmax (0.052) (6814) + 1500 - (0.1) (6814) - 2000 MWmax = 16.3 ppg ) ) Casing Detail ~PHILLlPS Alaska, Inc. Vi!§~'§.Il.~flc"e Çasinf/ ,¡W A Subsidiary of PHILLIPS PETROLEUM COMPANY Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Jts 3 to 64 Doyon 19 RKB to LDS FMC Gen V Hanger 62 Jts 9-5/8" 36# J-55 BTC Csg Davis Lynch Float Collar 2 Jts 9-5/8" 36# J-55 BTC Csg Davis Lynch Float Shoe Jts 1 to 2 9- 5/8" shoe @ TD 12 1/4" Surface Hole RUN TOTAL 37 BOWSPRING CENTRALIZERS· 1 per jt on Jt #1 - #12 (On stop rings of Jt #1 & #2) #14,16,18,20,22,24,26,28,30,32,34,36,38, 40,42,44,46,48,50,52,54,56,58,60,62 Last 9 joints stay out # 65 thru # 73. Use Best-Q-Life 2000 pipe dope Remarks: Up Wt -160 k Dn Wt -135 k Block Wt - 75 Well: Date: LENGTH 36.60 2.25 2638.33 1.57 83.81 1.73 2774.00 Supervisor: Don Mickey CD2~45 11f1S/01 DEPTH TOPS 36.60 38.85 2677.18 2678.75 2762.56 2764.29 ('~~ ~ ') PHILLIPS ALASKA INC. CementingRE!Port Legal Well Name: CD2-45 Common Well Name: CD2-45 Event Name: ROT - DRILLING Primary Hole Size: 12.250 (in) TMD Set: 2,764 (ft) Date Set: 11/15/2001 Csg Type: Surface Casing Csg Size: 9.625 (in.) Cmtd. Csg: Surface Casing Cement Co: Dowell Schlumberger ') Page 1 of 3 Report #: Start: Spud Date: 11/13/2001 1 Report Date: 11/15/2001 11/10/2001 End: Cement Job Type: Primary Squeeze Casing Hole Size: TMD Set: Date Set: Csg Type: SQ TMD: SQ Date: Cmtd. Csg: Cementer: Jerry Culpepper Squeeze Open Hole Hole Size: SQ TMD: (ft) SQ Date: SQ Type: Cmtd. Csg: Plug Hole Size: Top Set: (ft) BTM set: (ft) Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Pipe Movemént Pipe Movement: Reciprocating Rot Time Start: : Rec Time Start:01 :00 Time End: : Time End: 04:25 RPM: SPM: Init Torque: (ft-Ibf) Stroke Length: 25.0 (ft) Avg Torque: (ft-Ibf) Max Torque: (ft-Ibf) Drag Up: 160,000 (Ibs) Drag Down: 125,000 (Ibs) Type: Cement Casing Volume Excess %: 43.00 Meas. From: Time Circ Prior To Cementing: 2.25 Mud Circ Rate: 231 (gpm) Mud Circ Press: 260 (psi) Start Mix Cmt: 03:45 Start Slurry Displ: 04:33 Start Displ: 04:38 End Pumping: 05:15 End Pump Date: 11/15/2001 Top Plug: Y Bottom Plug: Y Stage No:1of1 Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 7.50 (bbl/min) 7.50 (bbl/min) Y 810 (psi) 1,200 (psi) 5 (min) Y Returns: full Total Mud Lost: (bbl) Cmt Vol to Surf: 100.00 (bbl) Ann Flow After: N Mixing Method: Density Meas By: Type: Non-Disp. LS Density: 9.6 (ppg) Visc: 71 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type: Mud PVIYP: 21 (cp)/16 (lb/100ft2) Gels 10 sec: 16 (lb/100ft2) Gels 10 min: 26 (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: 9.6 (ppg) Volume: 187.00 (bbl) Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Mud Data Stage No: 1 Slurry No: 1of4 To: (ft) Description: Biozan waterw/ nut plug Cmt Vol: (bbl) Density: 8.30 (ppg) Slurry Vol: (sk) Water Vol: (bbl) Class: Yield: (ft3/sk) Other Vol: 0 Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Purpose: SPACER Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 11/27/2001 3:54:55 PM ) .<,~) ~ Legal Well Name: CD2-45 Common Well Name: CD2-45 Event Name: ROT - DRILLING 51 urry Data Fluid Type: FLUSH Slurry Interval: (ft) To: (ft) Water Source: ) PHILLIPS ALASKA INC. Cementing Report Page 2 of 3 Report #: Start: Spud Date: 11/13/2001 1 Report Date: 11/15/2001 11/10/2001 End: Stage No: 1 SlurryNo:2of4 Description: ARCO spacer Class: Cmt Vol: (bbl) Density: 10.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: CF) Temperature: (OF) Temperature: (OF) Temperature: (OF) Slurry Data Fluid Type: PRIMARY Slurry Interval: 2,264.00 (ft)To: (ft) Water Source: Time Compressive Strength 1: Compressive Strength 2: Temp (OF) CF) Stage No: 1 Slurry NO:30f4 Description: ASLite Cmt Vol: 308.0 (bbl) Slurry Vol:389 (sk) Class: Density: 10.70 (ppg) Yield: 4.44 (ft3/sk) Water Vol: (bbl) Other Vol: 0 Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Stage No: 1 Slurry No: 4 of 4 Slurry Data Fluid Type: PRIMARY Description: Slurry Interval: 2,764.00 (ft)To: 2,264.00 (ft) Cmt Vol: 48.0 (bbl) Water Source: Slurry Vol:237 (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Temperature: (OF) Temperature: (OF) Temperature: (OF) Class: G Density: 15.80 (ppg) Yield: 1.15 (fP/sk) Water Vol: (bbl) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Temp (OF) CF) Purpose: SPACER Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Purpose: Lead Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Purpose: TAIL Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Printed: 11/27/2001 3:54:55 PM ') ) <'~ TfTiI ~ PHILLIPS ALASKA INC. Cementing Report Page 3 of 3 Legal Well Name: CD2-45 Common Well Name: CD2-45 Event Name: ROT - DRILLING Report #: Start: Spud Date: 11/13/2001 1 Report Date: 11/15/2001 11/10/2001 End: Casing Test Shoe Test liner Top Test Test Press: 2,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: Y Pressure: 16.00 (ppge) Tool: N Open Hole: 30 (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N log/Survey Evaluation Interpretation Summary CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: N Bond Quality: Temp Survey: N Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: N Number of Remedial Squeezes: Printed: 11/27/2001 3:54:55 PM ) ) ~.. (I Phillips Alaska, Inc. rD Daily Drilling Report Well Sidetrack AFE 24 Hrs TMD TVD DFS Prog CD2-45 CD2-45 998D12 0' 2,7741 2,389' 3 Superviso . Don Mickey Proposed TMD Daily Cost Rig Name Doyon 19 Field Name Current Status Event Code 24 HR Forecast 12,9061 $244,593 .~ REPT NO. DATE 11/15/01 4 Pressure Test(s) Type I Date I TM D I TVD I MW I Press I To:. press I EMW 110'10'10 ppglO psilO.OO psilO.OO ppg Alpine Cumulative Cost $725,199 Last Safety Meeting Incident 1st 24 hrs ~No Circulate for casing test ODR Test casing - drill out - FIT - Drill 8.5" hole Last Survey TMD: INC: Azi m: BOP Tst (Last I Next) Rig Accept 11/12/01@ 18:00 Rig Release @ : 11/15/01 111/22/01 Last Casing Next Casing Operations Summary Hours Phase ActivitySubcode Tcilme TroubleOperation ass From To 00:00 00:30 00:30 01:00 01:00 03:00 0.5 SURFAC CASE RUNC 0.5 SURFAC CEMENT PULD 2 SURFAC CEMENT CIRC 03:00 04:30 1.5 SURFAC CEMENT PUMP 04:30 05:30 1 SURFAC CEMENT DISP 05:30 07:30 2 SURFAC CEMENT PULD 07:30 10:00 2.5 INTRMl DRILL RIRD 10:00 15:00 5 INTRMl DRILL RIRD P P P MU landing joint - Land casing in wellhead on mandrel hanger wi shoe @ 2764' FC @ 2677' RD casing equipment & RU cement head Circulate & condition mud for cement job - recip. pipe PJSM - Cement 9 5/8" casing - pumped 40 bbls Biozan water wlnut plug as marker - pump 5 bbls water fl Dowell - Test lines to 2500 psi - Drop bottom plug - Pump 50 bbls ARCO spacer @ 10.5 ppg - Mix and pump 308 bbls lead slurry @ 10.7 ppg - observed nut plug @ sharkers - Switch to tail cement - Pumped 48 bbls tail slurry @ 15.8 ppg - drop top plug wi 20 bbls water fl Dowell Displace cement wi rig pumps wi 9.6 ppg mud @ 7.5 bbls/min slowed pumps wi 20 bbls displacement remaining to 4 bblsl min. Bumped plug wi 186.5 bbls - pressure to 1200 psi - release pressure - floats held - CIP @ 0515 hrs - full returns wi 100 bbls cement returns to surface RD cement head - LD landing joint - Flush & drain stack ND diverter - attempt to pull starting spool & 20" Hydril - Unable to lift - Flush 20" Hydril & starting head - Observed junk wedged between hanger & landing ring RU 350 ton elevators - MU landing joint - Pick up on 9 5/8" casing 8" - Observed junk fallout between 16" x 9 5/8" annulus - slack off on casing - LD landing joint - Remove 20" Hydril - OPER Observed mandrel hanger not landed in landing ring - 4" high - Conferred with Drilling Team Leader in Anchorage - PU landing joint - PU on 9 . ,." . " . P P P P T 18:30 casing - - )ng set boo high - LD landing joint Install FMC Unihaed & test metal to metal seal to 1000 psi Nipple up BOPE Set test plug - Test BOPE - pipe rams,blind rams, choke & kill line valves, choke manifold valves, floor safety & dart valves, top drive IBOP valves to 250 psi & 5000 psi - Hydril to 250 psi & 3500 psi - Perform Accumlator closure test - test witnessed & approved by Chuck Scheve AOGCC RD test equipment - blow down lines - pull test plug - set wear bushing Finish running casing - Cement casing w/ 308 bbls lead & 48 bbls tail slurry - NU diverter - NU well head & BOPE - test BOPE -) 15:00 16:30 16:30 1.5 INTRM 1 DRILL RIRD P 18:30 2 INTRM1 WELCTL NUND P 23:00 4.5 INTRM 1 WELCTL BOPE P 00:00 1 INTRM1 WELCTL NUND P 23:00 24 Hr. Sum: Injection Date Sou rce Volume Destination Total for destination 11/26/01 CD2-45 1,123 CD2-14 9,098 Source Total: 9,098 Mud Data , Mud Density FV PV /yp 10se~ / 10 min / WL/HTHF MBT Flowline Drilling Compan T PH ype 30 mln Gels Temp Solids MI Spud Mud 9.6 38 10/ 15 4/8/9 8/0 15 8.4 0 3.7 ~, ...~ Well Name: CD2·45 CASING TEST and FORMATION INTEGRITY TEST Date: 11/16/01 Supervisor: D. Mickey Reason(s) for test: o Initial Casing Shoe Test o Formation Adequacy for Annular Injection o Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8", 36#, J·55, BTC CSG Casing Setting Depth: 2,764' TMD Hole Depth: 2,794' TMD 2,389' TVD 2,403' TVD Mud Weight: 9.6 ppg Length of Open Hole Section: 30' EMW= Leak-off Press. + Mud Weight = 800 psi + 9.6 ppg 0.052 x TVD 0.052 x 2,389' Used cement unit Riç¡ pump used 4,000 psi 3,900 psi 3,800 psi 3,700 psi 3,600 psi 3,500 psi 3,400 psi 3,300 psi 3,200 psi 3,100 psi 3,000 psi 2,900 psi 2,800 psi 2,700 psi 2,600 psi 2,500 psi ~ ~:~gg ~~: ::) 2,200 psi ~ ~:¿gg ~~: w 1,900 psi 0:: 1,800 psi c.. Hgg ~~: 1,500 psi 1,400 psi 1,300 psi 1,200 psi 1,100 psi 1,000 psi 900 psi 800 psi ~.. _ r... 700 psi J- ~gg ~~: ~J'" 400 psi 300 psi 200 psi 100 psi o psi o 10 EMW for open hole section = 16.0 ppg NO #2 Pump output = 0.0997 bps Fluid Pumped = 1.1 bbls Fluid Bled Back = 0.8 bbls ! ITIME LINE I' ONI!: M NUT TICKS 111111 /~ ~LEAK-OFF TEST ~ CASING TEST U LOT SHUT IN TIME .....,.,.,~ CASING TEST SHUT IN TIME -+-TIME LINE I 20 30 STROKES 40 50 NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above Modified by Scott Reynolds LEAK-OFF DATA 60 MINUTES FOR LOT STROKES PRESSURE t--------------.. -r---------------r-----------------., : I 0 : 0 psi I t~~~=~~~~~~~~~~r~~~~!~~~~~~~~~~~~I~Ë~~~~~~~ : I 2.0 : 60 pSI ; r------------r----3~Õ------r---r7õ-psT--l I::===:::=EI~:::£:~{H~B : : 6.0 : 480 pSI : r------------r----:rÕ-----r--S4õ-psT-l ~~~~~~~~~~~~~~~~r~~~~~~~~~~~~~~~~~~~~~ë~r~~ : I 9.0 I 660 pSI : F~~~=~~~~~~~~r~~~f~~~~~~~~F~~~~~~tF~i r---------------T---------------r----- -------- ---, ~:=:=::::=::f::===:::::f:::::::==:=::1 r---------------T---------------r----------------, t~~=~~~~~~~~~~t~~~~~~~~~~~~j~~~~~~~~~~~~~~~~j t---------------t--------------+---------------i r---------------T---------------r---------------, t~~=~~~~~~~~~~t~~~~=~~~~~~~t~~~~~~~~~~~~~~~~ I I I I I I I I f-------------¡ I I i I I I ¡ SHUT IN TIME ¡ SHUT IN PRESSURE !:::t~:~H::::==:=:::E~~~:::J ¡ 2.0 min ! ! 750 psi ! 1~1~~~~ì~~E~~~~~~~~~E~iii~~] : 6.0 mln I I 660 pSI : E:;:1:~ItE:::=:==:[:::J.~;:~~EJ ; 9.0 nlin I : 640 pSI : [~~~º~Q~~J~~I~~~~~~~~~~~~~I~~~~~~ë~}~~] .PHlllIPS Alaska, Inc. ~ A Slbsidiary of PHilLIPS PETROLEUM COMPANY CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ~~~~~~~~~~~~~~~~¡=~~~~!E~~~~¡~~~~Q~ë~}~~~~~1 : : 2 stks I 140 psi : F~~~~~~~~~~~~~F~~:~~~t~~~F~~~~~~~~F~1 [~~~~~~~~~~~~~¡~~I~f~~~~~r~I~~~~!~~~1 ! : 10 stks I 930 psi : ¡---------------r-12-stks--r1~Õ9Õ-psT-! r--------------T--1-.ïsfks-I-1~2šõ-psTl r---------------rT6-sfks--r1~43Õ-pSi--1 }---------------+--------------+-------------.--t : : 18 stks I 1,600 pSI I ¡--------------r-2õ-sfks--r1~8õõ-psTI r---------------r-22sfks--r2~õ4õ-psTl r---------------T--2.ïsfi{s--r2~27Õ-psTl }--------------- +-------------+--------------.--t : I 26 stks I 2,480 pSI : f~~~~~~~~~~~~~~~FI?~~!~~~~F~~~?~~ë~I~1 r- -------------- T- ------------T---- - -----------1 t~~~~~~~~~~~~~~t~~~~==~~~~~t~~~~~~~~~~~~~~~l t--------------t--------------t----------------t I . , I ¡ SHUT IN TIME ¡ SHUT IN PRESSURE ~--------------+--------------------------------- ! 0.0 min : ¡ 2.520 psi ¡ F~~~~~~~R~~F~~~~~~=~~~~~F~~~~~~~~F1 ~~~~~~Q~~~~~r~~~~~~~~~~~~~r~~~~~~ë~~~~1 : 4.0 mln : I 2,480 pSI : F~~~~~m~~F~~~~~~=~~~~~F~~~~~~~tF1 ~~~TQ~~~~~~¡~~~~~=~~~~~~~r~~~~~~ë~~~~1 : 8.0 mm : ; 2,460 pSI I !---i{rñi1ñ--r---------mr2~46õ-psyl rTõ~õî;;¡ñl-------------r2~4šõ-psyl rT5~Õ-ñ;¡ñ--r------------r2~4ŠÕ-psrl }-----------:---+--------------+--------------.--t ; 20.0 mm I : 2,440 pSI : a~:~!H::::::==:::B:~;H~::j "-' ..~ NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ) ) Casing Detail 7"/fJl?rmJ¿çJiatft J~,ª<s¡nª Phillips Alaska, Inc. Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Doyon 19 RKS to LOS FMC 11" X 7" Hanger Jts 3 to 245 243 Jts 7" 26# L-80 STCM Csg 7" Davis Lynch Float Collar Jts 1 to 2 2 Jts 7" 26# L-80 STCM Csg 7" Davis Lynch Float Shoe 8-1/2" TO 1 straight blade centralizer per jt #1 to # 23 & # 176, 177, 178 then every other jt f/ # 180 to # 242 58 total centralizers Use Best-a-Life 2000 pipe dope Remarks: Up Wt = On Wt = Block Wt= 70K Well: Date: LENGTH 34.23 1.62 9849.54 1.45 83.20 1.70 Supervisor: Don Mickey CD2~45 11/22/01 DEPTH TOPS 34.23 35.85 9885.39 9886.84 9970.04 9971.74 9982.00 ~ @ ') PHILLIPS ALASKAINC~ Cementing Report Legal Well Name: CD2-45 Common Well Name: CD2-45 Event Name: ROT - DRILLING PrimarY Hole Size: 8.500 (in) TMD Set: 9,972 (ft) Date Set: 11/23/2001 Csg Type: Production Casing Csg Size: 7.000 (in.) Cmtd. Csg: Production Casing Cement Co: Dowell Schlumberger Rot Time Start: Rec Time Start: Time End: Time End: Type: Volume Excess %: Meas. From: Time Circ Prior To Cementing: Mud Circ Rate: (gpm) Mud Cire Press: (psi) Report #: Start: 2 11/10/2001 CementJobType:Prirnary Squeeze Open Hole Hole Size: SQ TMD: (ft) SQ Date: SQ Type: Squeeze Casing Hole Size: TM 0 Set: Date Set: Csg Type: SQ TMD: SQ Date: Cmtd. Csg: Cmtd. Csg: ) Page 1 of 2 Spud Date: 11/13/2001 Report Date: 11/24/2001 End: Plug Hole Size: Top Set: (ft) BTM set: (ft) Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Pipe Movement· Pipe Movement: No movement Cementer: Jerry Culpepper RPM: SPM: Init Torque: (ft-Ibf) Stroke Length: (ft) Avg Torque: (ft-Ibf) Drag Up: (Ibs) Stage No:1of1 Start Mix Cmt: Start Slurry Displ: Start Displ: End Pumping: End Pump Date: Top Plug: Bottom Plug: (bbl/min) (bbl/min) Y 600 (psi) 1,200 (psi) 5 (min) Y Y Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: Mud Data Max Torque: (ft-Ibf) Drag Down: (Ibs) Returns: Total Mud Lost: Cmt Vol to Surf: 468.00 (bbl) (bbl) Ann Flow After: Mixing Method: Density Meas By: N Type: Non-Disp. LS Density: 9.7 (ppg) Visc: 41 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type: Mud PVIYP: 6 (cp)/18 (lb/100ft2) Gels 10 see: 6 (lb/100ft2) Gels 10 min: 11 (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: 9.7 (ppg) Volume: 378.00 (bbl) Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) To: (ft) Water Source: lake Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: ("F) Stage No: 1 Slurry No: 10f 2 Description: ARCO Spacer Class: G Cmt Vol: (bbl) Density: 12.50 (ppg) Yield: (ftJ/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Purpose: PRIMARY Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 11/27/2001 3:03:06 PM ) ) ~ ~ ~ PHILLIPS ALASKA INC. Cementing Report Page 2 of 2 Legal Well Name: CD2-45 Common Well Name: CD2-45 Event Name: ROT - DRILLING Report #: Start: 2 11/10/2001 Spud Date: 11/13/2001 Report Date: 11/24/2001 End: Stage No: 1 Slurry No: 2of2 Slurry Data Fluid Type: PRIMARY Description: Slurry Interval: 9,972.00 (ft}To: 9,010.00 (ft) Cmt Vol: 33.8 (bbl) Water Source: Slurry Vol:165 (sk) Class: G Density: 15.80 (ppg) Yield: 1.15 (fP/sk) Water Vol: (bbl) Other Vol: 0 Purpose: PRIMARY Mix Water: (gal) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) Casing Test Shoe Test LinerTopTest. Test Press: 3,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: Y Pressure: 12.60 (ppge) Tool: N Open Hole: 30 (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N Log/SurvéY Evaluation Interpretation Summary CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: N Bond Quality: Temp Survey: N Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: N Number of Remedial Squeezes: Got casing on bottom & began circulating @ 1.5 bblsl min for 30 mins. - increased pump to 2.0 bbls/ min for 30 mins. - Lost returns - Fluid level dropped to 20' and was static - cemented 7" casing - observed perssure increase as cement rounded the corner - fluid level remained static @ 20' during job - no annulus flow Printed: 11/27/2001 3:03:06 PM ) ) ~' (I Phillips Alaska, Inc. Ilm Daily Drilling Report Well Sidetrack AFE 24 Hrs TMD TVD DFS Prog CD2-45 CD2-45 998D12 0' 9,982' 7,167' 12 .., REPT NO. DATE 13 11/24/01 Superviso' Don Mickey Proposed TMD Daily Cost Pressure Test(s) $200,526 Type I Date I TMD I TVD I MW I Press I To:. press I EMW FIT 111/16/0112764'12389'19.6 ppgl800 psi1,991.40 $2,121,903 '116 05 pSI . ppg BO P Tst (Lastl Next) Rig Accept 11/12/01@ 18:00 Rig Release @ : 11/23/01 11/24/01 112/1/01 12,906' Rig Name Doyon 19 Field Name Cu rrent Status Event Code 24 HR Forecast Alpine Cumulative Cost 51' & C t D'III" Last Safety Ip u I me Meeting ODR Incident 1st 24 hrs ?No Test casing - F.I.T. - Prep pits for OBM Last Survey TMD: INC: Azim: Last Casing Next Casing Operations Summary From To Hours Phase ActivitySubcodE Tcilme TroublEOperation ass 16:30 19:00 2.5 PROD DRILL PULD T EQIP Circulate @2.0 bbls/ min. - lost returns - monitor well - fluid level dropped 20' and remained static - Noified Drilling Team Leader Cemented 7" casing - Pumped 5 bbls water - test lines to 3000 psi - pumped 50 bbls ARCO spacer @ 12.5 ppg - dropped bottom plug - mixed & pumped 33.8 bbls. 15.8 ppg cement - Dropped top plug w/ 20 bbls. water f/ Dowell - switched to rig pupms & displaced w/ 9.6 ppg mud @ 5 to 7 bbls/ min. - bumped plug w/ 1200 psi - floats held - CIP @ 02:20 hrs. - No returns during job - fluid level remained static @ 20' LD - cement head, landing joint, elevators & long bails - PU shrot bails & 5" elevators - PU stack washer - wash stack - pull thin wall wear bushing Set pack off & test to 5000 psi for 10 mins. Change top pipe rams f/ 7" to 3 1/2" x 6" & change saver sub in top drive Set test plug - Test BOPE - Choke manifold valves, choke & kill line valves, floor TIW & dart valves, top drive !BOP valves, pipe rams & blind rams to 250 psi low & 5000 psi high - Hyrdil to 250 psi low & 3500 psi high - Perform accumlator recovery test - Witnessing of test waived by Jiohn Crisp AOGCC - pull test plug & set wear bushing - blow down choke & kill lines PJSM - PU BHA # 3 - load RA source in MWD - Test MWD - PU PBL tool - Attempt to test tool - tool would not lock open - lay down tool - observed bent cullet on latch up assembly - also found metal shavings inside tool (looks like f/ recut on box) POOH w/ BHA to check MWD - Pull RA source - .. - - 00:00 00:30 0.5 INTRMl CEMENT CIRC P 00:30 02:30 2 INTRMl CEMENT PUMP P 02:30 04:00 1.5 INTRMl CEMENT PULD P 04:00 05:00 1 INTRMl DRILL OTHR P 05:00 06:00 1 PROD DRILL OTHR P 06:00 13:30 7.5 PROD WELCTL BOPE P 13:30 16:30 3 PROD DRILL PULD P 19:00 22:30 3.5 PROD DRILL OTHR T EQIP PBL too. )install probe - load RA source - RIH - Check back up PBL tool - found metal shaving inside tool from recut also - clean out tool - PU & attempt to test - PBL tool would not lock open - as per vendors operating instructions - LD PBL sub PU jars & 2 jts. 4" HWDP ) 22:30 24 Hr. Sum: 00:00 1.5 PROD DRILL TRIP P Injection 11/25/01 CD2-45 10 Source Total: 7,975 .ç.!d..?.::14. Total for destination 7,975 Date Source Volume Destination Mud Data companJ Mud Density FV PV /YF 10se~ / 10 min / WL/HTHF MBT PH Flowline Drilling Type 30 mm Gels Temp Solids MI Non-Disp. 9.6 37 7/18 7/9/10 4/9 15 9.1 0 2.9 LS Bits Bit/Run Size Manuf. Type S=~~I Jets or TFA D;~tt Date In I-O-D-L-B-G-O-R 3/3 6.125 HU~~~S- STR386DG2K 1905752/0.46875/0.46875/0.46875 9982' 11/24/01 0-0-- --- - ~ ~ Well Name: CASING TEST and FORMATION INTEGRITY TEST 11/24/01 CD2-45 Reason(s) for test: Date: Supervisor: D. Mickey o Initial Casing Shoe Test o Formation Adequacy for Annular Injection o Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8" 36# J-55 BTC X 7" 26# L-80 BTMC Casing Setting Depth: Mud Weight: 2,764' TMD 2,389' TVD Toe Hole Depth: 9,010' TMD 6,814' TVD 9.6 ppg Length of Open Hole Section: 6,246' EMW = Leak-off Press. + Mud Weight 0.052 x TVD = 540 psi 0.052 x 2,389' + 9.6 ppg Used cement unit Riç¡ pump used 700 psi 600 psi 500 psi UJ 400 psi ~ => CI) CI) UJ ~ 300 psi Q. 200 psi 100 psi o psi 'f · · I 0 yes #2 / J EMW for open hole section = 13.9 ppg Pump output = bbls pumped Fluid Pumped = 5.5 bbls Fluid Bled Back = 0.0 bbls ( I I~~~f TIME LINE I ONE MINUTE TICKS -.''''': · LEAK-OFF TEST -0- CASING TEST LOT SHUT IN TIME --,,0;,- CASING TEST SHUT IN TIME -+-TIME LINE 10 12 14 BARRELS 20 22 16 18 NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above Modified by Scott Reynolds LEAK-OFF DATA 24 MINUTES FOR LOT BBLS PRESSURE r------- ---------r- ------Õ-------r-----õ-p-ši----l [=:=:::::l:If::]:=::~]~¡J : : 1.5 : 5 pSI : 1:::==::=:::]:::3I:::E~~~~:=J : : 3.0 : 56 pSI : r-------------r----3~!f----T--:¡-õfrpsT-l r~~~~=~~~~~~~~~¡~~~~~~~º~~~~~~~~~~~~~Ië~r~~ I I 4.5 : 207 pSI : F~~~~~~~~~~~~~t~~~~~~~~~~~~~~F~~~~~~~F~i C~~~=~~~~~~~~r~~~~~~º~~~~~J~~~~Ië~~~~~~ : : 6.5 : 439 pSI : F=~~~~~~~~~~~t~~~~~~~~~~~~~~F~~~~~~~F~i r~~=~~~~~~~~~~¡~~~~~~I~~~~~~~~~~~~ë~~~~~~ : I 8.5 : 535 pSI : t~~~~=~~~~~~~~t~~~~~g~~~~~~~~t~~~~~}~~:~~~i r~~~=~~~~~~~~~~¡~~~=1~~º~~~~J~~~~~~ë~~~~~~ : : 10.5 : 530 pSI : r--------------r-----.¡T.-õ-----¡---S3Õ-psT-1 r--------------l 11.5 ! 525 psi ! ¡ SHUT IN TIME ¡ SHUT IN PRESSURE ¡~~~ij~~ß~]~~~~~~~~~~~~[i~~~~j : 3.0 min I : 318 psi : 1::~I:II~:t~:-~:~:~-:::I:::¡fa:~:1 ! 9.0 min ! ! 258 psi i [I~Q~~}~~I~~~~~~~~~~~~~I~~~~~~ë~)~] mPHILLIPS Alaska, Inc. ~ A Slbsidiary of PHILLIPS PETROLEUM COMPANY CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ..---------------.,.---------------.,.-----------------" : : 0 stks: 0 psi : l~~~~~~~~~~I~~~~~~~~T~~~~~~~~~~] g~~~~~~~~I~~~~~~~~~~~l~~~~~~~~~~~~1 !~~~~~~~~~~~~~~g~~~~~~~g~~~~~~~J ¡~~~~~~~~~~~~f~~~~~~~~~~~g~~~~~~~~1 ¡:::~~=::==:t::::::=:::=t:::::::=::::: i i : : : SHUT IN TIME : SHUT IN PRESSURE ¡:::~~~H:::=:::::::::E::~:~~~=:::I ! 2.0min ! ! ! r-----------:----.,.---------------,-----------------,. : 3.0 mln : : : ¡~~~~r:¡¡ß~~r~~~~~~~~~~[~~~~~~~] : 7.0 mín : : : [fJ~%f~~f~~~~~~~~I~~~~~~~~~~] : 15.0 mín : : I [Ii~~¡¡~r~~~~~~~~~r~~~~~~~~~~~~! ,~/ '~ NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ) ) tPHILLlPS\ Philli Alaska, Inc. s ":='1"'.. , ~~' . -:7":"-;,." ", '~~I ~:r; 'fI'~ ~, ~. -'"""-íI;t-~~'";'.--'-"'· '.,, .................·..··..·ë~~·~t·~·d··¡;y ï;;;;¡~·h·~;ï... Data ploUed : 26-Nov-2001 Plot Refc(cmco ¡II MWD w/IFR <O-?'i'?'>. Coord¡natCl~ arC! 1n toot rerorcncCl :llot #45. Truo Vartica Dopthll are reforenca RK8(Doyon19). Rill. 1IffiI1I& ,...........,...'.!fm~. ......1 I CD#2 Field Structure Well: 45 Field: Location : North Slope, Alaska East (feet) -> Scele 1 inch = 400 ft 1600 2000 2400 2800 03200 03600 4000 HOD 4800 5200 5600 6000 6400 6800 7200 J200 2800 20400 2000 I ¡ I I I I I , I I I I I I I I I I I I I I I I I I I , , I I , , , , ! , I 5200 tI1 a ii" ;::: 5200 ~ II .<: c [ill, '\\ '\ \ \ '\ \ \\ ~, Coolo, \ \ ] ~ \\ \ \ \ \ \\ \ \\ \ \\\ '\ \\ \ \ \\ ~ - 2400 2400 - - 2000 2000 - 1600 - f!}:¡ 1200~""""'"'''''''''''''''''''' 600 ~ ~..~....._..,..~.. ""':":~~~;::;';;;;;:;~::"" ~/,/.-:;:;;;l /"/ ./ / . , -_...~..-_.....;.~;.."."" ;' ""...../. J. rf!Fx........- , ,// /....... ; ~/IJ Cf4lln;-,£' I 1200 ...~,/'.... I V 1600:#// / / / / /// ! 2000 ~ ø'/; (f) o c: 5= ., ., "'" ..c: "5 o (f) ...., CD CD '-' I V \ \ \ \ , \ \ " \ \ , \. , \~ 1\<- '\\ \\\\ ~, / / / .I ,/ / / í .I - J200 3200 - ~ m:J / -~ ~2CO - \ \"\\'.""'tI ! I , , , I , \ , I I , , , I I , I I , , , , , , , 3500 4000 4~OO 4800 ~200 ~ 6000 6iOO 1)800 7200 1600 2000 2400 3200 2800 HOO 2000 East (feet) -> Scele 1 inch = 400 ft ") ) ··..·........·ë·~~~t~d..bÿ··b~·¡~·h·ä~ï·h . Data plotted: 26-Nov-2001 Plot Reforence ill MWD w/IFR <O-??1'), CoordJnata8 are In feat raforanca slot N45. True Vertical Dopths ora rof"ronco RK8(Doyon19). ..tIIIlII IIfIl!a }P.~~.!!_!P__~___.~}.~_ s k a , In c . ~HI~LlPS\ Locotion : North Structure CD#2 Field : Field Well: 45 .........m......................!~.~~.............n.nn.m..m...m.....n.... Scale 1 inch ~ 100 It Eost (feet) -> 1000 1100 1200 1.300 1400 IS00 1600 1700 1BOO 1'Î100 2000 2100 2200 2.300 2400 I , I I I I I 1000 JOO 1000 JOO - U1 I g :f .s:: :; (1) 0 (1) U1 I I V V @ 1000 1100 1200 , , , . , , , , ,'~ % .~ - 1900 UOO I4.QO 1~ 1600 1700 1800 1900 2000 2100 2100 2JOO HOD 1900 JOO I I I I I , , W~, ,f] . ~, .~~ , Scole 1 inch - 100 It Eost (feet) -> SURFACE CASING SHOE SEPARATION FROM CD2-45 CD2-45 X Y Surface Casing Shoe ASP 4 Coordinates: 372765.13 5973853.74 Distance Surface Surface Permit Cement Casing No. of Start End from Object csg.Shoe csg. Shoe Y Wells Permit # Date Report Tally LOT Source well Ann. Vol. Date Date well* X Coord. Coord. CD2-35** --- ----- x x 1 ---- ---- ---- 481.58 372312.31 5974017.68 CD2-39 301-281 1 0/9/01 x x 2 CD2-15, CD2-47 27879 10/10/01 11/12/01 469.55 372350.61 5973633.17 CD2-14 301-288 1 0/9/01 x x 2 CD2-45 10247 11/13/01 1241.90 372202.4 7 5974960.87 * Distance in feet, between surface casing shoes, in the X- Y plane ** CD2-35 was drilled from an ice pad in early 1998. The 9-5/8" x 7" annulus has not been permitted for annuluar disposal. '-' .'-~ r-- ) .FROM :~RCO DRILLING DOYON . . . 9Ø7 263 3141 1 (:'''·8 , Ø3 - 2Ø ) Casing Detail 9.625" Surface Cas;nø ARca Alaska, Inc. Su~ióiary of Atluntç Rlch~ld Company # ITEMS COMPLETE DESCRIPTION Of EQUIPMENT RUN Doyon 141 RKB_to Ice Pa~ = 29.5' Above RKB jts. 60.84 jt. 90_ jt. 89 jts_. 3..5; jts 1-2 9 5/8" Landing Joint 9 5/BII. 40#, L-eO BTC 9 S/8", 40#. L-80 BTC (Thread Locked ColI~r) Gemeco 9 5/8" Stage Collar 95/8",40#, L-80 BTC rrhread Locked Collår) 9 5/8". 40#, L-80 BTC Gemeco Float Collar 9 5/8", 40#, L-SO BTC Gemeco Float Shoe 40 Gemeco Bow Spring CENTRALIZERS Run çentralizers in center of Jts. 1,2, 89,90 over st~op conan; and over casing collars on Jts. 3-14 and over collars of jts. 17 .20.23.26,29,32,35.38.41 ,44,47.50.53,56,59,82.65,68,71,74.77,80, 83 and 84 - . Joints 86-88 (4 join~s) will remain in the pipe shed. 09:ØS "261 P.01/01 WELL: CD2.35 DATE: 3116198 1 OF 1 LENGTH 31.93 953.74 38.45 2.85 3e.4B 2185.08 1.47 84.81 1.75 PAGES DEPTH TOPS -10.54 -10.54 21.39 975.13 1013.58 , 016.43 1052.89 3237.97 3239.44 3324.25 ~22e .00 -, - Remarks: String Weights with Blocks: 130K#Up.105K# Dn,20kiBfocks. -Ran 86 joints of casing. Drifted casing with 8.679 plastic rabbi!. Used Ardic Grade API Modified No Lead· thread compound on aU connections. Casing is no~ost~. Doyon 141 DriIJing Supervisor:Robert L Morrison Jr. -----..------------,--~-- ·~-,---~.,_.._----_._- ). ~. ...~ ..,.,. ARCa Alaska, Inc. I Well Name: CD2-35 Rig Name: DOYON 141 Report Dale: 03120198 AFC No.: 998871 Cementing Details I Report Number: 1 Field: ALPINE Casing Size Hole Diameter: I Angle thru KRU: Shoe Depth: I lC Depth: I 9·518 12.25 3326 1013 CentrallzelÌl ,._. :{;:. /....,:: ~-r' J!,¡:1~¡~;;: - . Stat~ type used. intervals coverea and SpiJClng COinrriënt!i"·-' - '-." '" ~,"!-"., \~~;;;~~~::.!:_.,~> ~<:/,1~:;{':~~ 40 GEMECO BOW SPRING CENT, CENTER JTS 1,2,89,90 OVER EVERY 3RD CLR F/SHOE TO SURFACE. .M~j.~'~ Welghl: PV(pnor cond): PV(after cond): VP(pnor cond): 10.0 115 26 29 "10 washou\: VP(after cond): 43 GelS belore: 14120 Gels atler: 16/23 Total Volume CIrculated: 3HRS. Typf': Volume: Weight: Type: \/Oiume: Weigh\: MIX wtr lemp: 70 No. 01 SaCkS: 150 Weight: 10.5 Yield: 4.45 . Additives: D41.6%,D53 30%,0791.5%,0124 50%,5.11.5% Type: Mix wlr temp: 70 G No. of Sacks: 350 Weight: 15.8 Yield: 1.17 Aadiuves: '. D46 .2'Y.,065 .3'Y.,S·1 1% l' Rate(belore ta,1 al shoe). ',..," ; 5.5 BPM ~. J-~~fø.(¡i.~ :"~:~~;~f' Reciprocation lenglh' ~i~~~~:::~'l ;:"e..a,_øne" Calculated top of cament : Rate(lall around Shoe): 5.5 Reciprocation speed: 1 MIN Actual Displacement: 214 Sir. WI. Up: 130 Sir. WI. Down: iDS Sir. Wi. in mud: CP: 0906 Bumped plug: y Floats held: y Remarks:STAGE CLR @ 1013' PERFORMED TWO STAGE JOB THRU STAGE CLR, CMT TO SURFACE SWlTHCHED TO TAil, FULL RETURNS THROUGHOUT. Icement Company: OS I Rig Contractor: DOYON IAPproved By: R.W. SPRINGER --'-'--~-""-----'--"---'-------_."'--'--' _..._--~'_.._---- - ---.--- ) ) - ~.. Daily Drilling Report "" ARCO Alaska, Inc. AFC No. I Date RptNo I Rig Accept - hIS Days Since AccepVEst: 7 I Rig Relase . hIS: 998871 03119198 11 11:00:00 PM Well: CD2-35 Depth (MDfTVD} 3335/3127 Prey Depth MD: 3335 Progress: 0 Contractor: DOYON Dally Cost $ 118725 Cum Cost $ 1137337 Est Cost To Dale $ Rif;¡ Name: DOYON 141 Last Csg: 9·5/8 ~ 3326' Next Csg: 7" @ 9728' Shoe Test: Operation AI 0600: NIU BOPE Upcoming Operations: TEST BOPE, DRILL OUT. ~;"~'Möb.DA1A#:".JI""'!"- ~"DRlL'tING,DATA" .¡Þ:ì~~·~I\';"':-N-:.'· Brr;DATA.1ir~~þÞ'~!, ø:!i:'''l'' ,EH&S.~ .~, ":'..~ .p¡;~{S~RJLL.SIBOP.;DA't~~~:.'*' MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOP/DIVERT LAST BOP/DRILL LSND N TST WEIGHT ROTWT sIZe SIZE EMPLOYER LAST H2S DRILL LAST FIRe DRILL 10.o~ VISCO IT)' PUWT MAKE MAKE SPILL LAST CONFINED LAST SPilL DRILL 13lisqc N SPACE PVNP SOWT TYPE l'YPE TYPe 28/43 GELS AVG CRAG SERIAL NO SERIAl NO VOLUME 17 /241 APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED· 550 3.2 031191t1l BBLS HTHP WL TRQ BiM cEÞTHtN DEF'THIN . POTABLE WATER 119 mll30 mIn USED· BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WËlL U% 1R·18 HOLE VOLUME PUMP PRES ACT lAST ADT/AST SOURce WELL TEMP ·F -5 2530bbl I ~I / I CD2-35 MBT PU P NO WOB2 WOB2 RATE (bØm) WIND SPEED 10 18.5 III ph LINER SZ RPM 1 RPM 1 PRESSURE (psi) WINC DIRECTION 45· 1.5 III LGS $PM 1 TFA TFA DIESEL VOL (bbl) CHILL FACTOR ·F ·27.07 51.011% ¿JI 0 . PIT VOL M2 JETS JETS MUD VOL (bbl) ARCO PERSONNEL 11$00 III IIIII IIIII 2M DAILY MUO SPS 1 BIT COST BIT COST . WATER VOL (bbl) CONTRACTOR 211 SliD III 110 PERSONNEL iOTAL MUD SPP1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 17 $81314 III III III 450 COMPANY MUDWT GRADE GRADE TOT FOR WELL (bbl) SERVICE 6 BAROID III III III PERSONNel TOTAL so -~~~f '(~~~~__'rio.':Ì'..)RltlRtReÐAT~~~e«mm..:~ ;~~.OD.:'m""~,!; 1I\f~';.9,da¡!;;t~~ .$.L.;WEIGHT,'!.\<.õ:.' ·~;'.-.GRADE,:¡.. " ¡:OONNe.CnON(i; ~CU ~, 07:30 AM BHA NO BHA LENGTH DATE LAŠT INSPECTED: HOURS ON JARS: ~emrJ.~~Nf);¡t,~:i¡~;'I~~f.lOURSj~.\ij¡llr.t1~~~¡J~tl·~:op~"JÏiI~~,];).~ÓæRArJONS;:f,!BQM~~~. 12:00 AM 12:30 AM 0.50 CASG Other PJSM, CASG OPERATIONS. 12:30 AM 02:30 AM 2.00 CASG easing and CONT. RlH Wt9-6III- C.menUng Cuing and ' CøwnUng easing and CemenUng Casing and Cementing Callng and Cementing Casing and Cementing Other 02:30 AM 03:30 AM 1.00 CASG MIU STAGE COLLAR AND CIRC CSG VOLUME. 03:30 AM 04:30 AM 1.00 CASG CaNT RIH WICSG. 04:30 AM 07:30 AM 3.00 CASG WASH 40' TO 8TM, CIRC AND COND MUD. 12:00 PM 4.50 CEMENT SAFETY MTG WIDOWELL, MIX & PUMP 2 STAGE CMf AS PER PLAN. 12:00 PM 01:00 PM 1.00 CEMENT WASH UP SURFACE EQUIP, RIG DN CEMENT HEAD. 01:00 PM 011:00 PM 5.00 NU_ND CUT FLOW LINE, NIPPLE OFF RISER, PIU STACK. SET EMERGENCY CSG SUPS, CUT OFF CSG & LAY DN, HID DIVERTER STACK. PREP CSG STUB WELD ON SPEED HEAD ADAPTOR. BRING STACK IN CELLAR & NIU 011:00 PM 01:30 PM 3.50 NU_ND Other 08:30 PM 12:00 AM 2.50 HOOP Other 24.00 . Supervisor: R.W. SPRINGER Daily Drilling Report: CD2-35 03/19/98 Page 1 --~---~- -...'''..,.".----_., ...__ _ '_'R' .-._............... ---'''--- ..... --".~'-"'---..__... ~ ~ ~ '}-'] . CASING TEST and FORMATION INTEGRITY TEST Well Name: CD 2..35 ALPINE Date: 3/22/98 Supervisor: R.W. SPRINGER Casing Size and Description: 9 5/8", 40 ppf, L-80, BTC 3326'MD 3,142' TVD Casing Setting Depth: Mud Weight: 9.6 ppg EMW= Leak-off Press. + MW 0.052 x TVD Hole Depth: 3,142' TVD 910 psi + 9.6 ppg LOT = (0.052 x 3,142') = 15.2 ppg F~uìd Pumped = 1.8 bbl Pump output = 0.1010 bps 2.000 psi 1;900 psi t.8ØPPfii 1,700 pSi 1..000 .p&i 1.500 psi 1,400 psi :1.300pd - W 1,200 psi Œ . :::) 1;100 psi = 1,000 psi W 900 . 0:: psi C. BOOpsi .700 'psi 600 psi ðOO .psi 400 ,psi 300 psi 200 .p6Í 100 .psi Qpsi ~_~_4.6~.8. - .. .-.... . A .. r / ---LEAK.,OFF TEST ... """CASING TEST 1P 1~ 14 16 1,8 .20 _~ ,2-4 ~ ~8 39 ~ 34 36 ~ 40 .stks ~ tïtks Qks ~ .sIk6 .61k6 -6tks -&tk6 Qk6 Qks .stk& $Iks 6Ik6 6tk6 6tks STROKES -'----_.~.._- - .-_._----~.~-~._------ . , ........:: . ~-,: '\v·,...· ~.:..":-:.-,, I'~ ""'.'",- """; , . . ~ ., .... -..... .... - ,- ) ) CI.ing Detail 7" ProductJ9n C¡.'nrl ARCO Alaska. Inc. Sub5ldllry or Atlantic Richfield Complny # ITEMS , Jtl 20Sl-23e Jts. 4...207 jt. ~ Jts. 1-2 COMPLETE DESC'UPTION OF EQUIPM!NT RUN Doyon 141 K! to CSG HGR = 2~.a' 7", LAN"cING JT. 34,0' OVERALL LENGTH 7" FMC fluted mandrel hanger ' - 7",2., L·eo. erC·MOD 7", 26#.,L-80, BTC-MOD 7", 28#. L·80, BTC..MOD Weatheñol'Ø Float CoÏlar 7", 2e#, l-eO, eTe-MOD Weatherford Float Shoe -----.- - WEI.L: ALPINE CD2..36 DATE: 3/28/91 1 OF 1 PAGES LENGTH DEPTH TOpe 25.80 2.00 1160,79 84S1.57 3g.87 1.2B . 81.76 1.46 . . , 21 RAY OIL TOOL RIDGID CENTRAL.lilllt' & a BOWSPRING CEN'AALIZERI . _. . _..,--.-'....... . -.-._ .... ,. - 'rip.,. -, . aun rlàgld ctntrallElrs- on Jt!l~ t:-II. R~n bowsprinlit cent. 9" . .top c;oll.,.. ofJt. 11.,117 '& 1.. . Joints ZOe,Z~7 & 238 wilt remeln in the pipe shed. ¿ - -.... 25.80 27.80 11 (!Ie.59 ;650.16 96;0.03 9691.31 9773.07 9774.53 Rømlrk,/"Strlng Weights with· Block.: 1i5Kt Up,1 OOKIIDn,201U1 ~lock'.R.n2al Joint. of. (;IalDQ.. Drifted casing with pla~ic rab~it Us~d Arctic Grade API Modified No Lead thread compoynd of'!. ~II çonnedi.ons. Casing is non-co¡¡ted. Doyon 141 Drl¡,ing Svpervl,or:R. YI. SPRINGER -. ._.,._----._----'~-~-~.---- -,---. .---. ) ') . ~~ ~" ARC a Alaska, Inc. AFC No. I Date 998811 03130"8 Daily Drilling Report RptNo 22 I Rig Accept. hrs 03113/9812:00:00 AM 978217220 Prey Depth MD: 9782 Cum Cost S 2166798 Next Csg: 4·1/2" liner Days Since Accept/Est: 18/ Rig Relase - hrs: Well: CD2-35 Depth (MMVD) Progress: 0 Est Cost To Date S Shoe Test: Contractor: DOYON Daily Cost S 202900 Rig Name: DOYON 141 Last Csg: 7" @9775' Operation At 0600: PREPARING TO DRilL FLOAT EQUIPMENT. Upcoming Operations: FIT, DRILL AHEAD HORIZONTAL SECTION. ~MUD:ÐAt~IiDRll;l:Jt,IG DA1A4:0~~.BlTIDA"'.~',~~~~~-~-;tiW,;:¡;f"EH&S~'....'¡'t.-:W' ~1Q:I,1j!~:::';¡"-:tDRR±S1BOP.DATA~~ MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOPIDIVERT LAST BOPIDRILL LSND 7RR1 N TST 02l281i8 02l28/S8 WEIGH't ~OTwr SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRill II.~ '.125 VISC SITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 45sqc COP N SPACE PVNP SOWT TYPE TYPE TYPE 14 I 20 STR554 GELS AVG DRAG SERIAL NO SERIAL NO VOLUME 3085 7/91 1902029 APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFElY MTG DRILL WATER USED- 600 4.2 0313011I BelS HTHP WL TRQ eTM DEPTH IN DEPTH IN "jt POTABLE WATER 121 10.8mll3O mln ' USED· BBlS SOLIDS TRQ OFF t=OOTAGE FOOTAGE INJECTION WELL 10.0% 1R·11J HOLE VOLUME PUMP PRES ACT/AST ACT/AST SOURCE WELL TEMP of ·23 8S8Obbl 2100 I J I I I CD2-35 MeT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 10 17.5 11/ ph LINER 52 RPM 1 RÞM1 PRESSURE (psi) WIND DIRECTION 135' '.0 IIII1 LGs SPM 1 TFA TFA DIESEL VOL (bbl) CHILL FACTOR of -4i1.19 . 12.18% 15/151 I 0 PIT VOL GPM2 JETS Jets MUD VOL (bbl) ARCa PERSONNEL 110 $41111 11111 11III 1110 DAILY MUD SPS 1 BIT COST BIT COST WATER vOL (bbl) CONTRACTOR 28 S500 III 0.00 0 PERSONNEL tor AL MUD spp 1 DULL DULL 'fOT AL VOL (bbl) MISC PERSONNEL $189074 III III III 1110 'COMPANY MUCwt GRADE GRADE TOT FOR WELL (bbl) SERVICE 13 BAROID 11.I111 III III PERSONNEL TOTAL 47 6·1/8" PDC BIT,NAVlDRlLL MACH 1XL(AKO 1.20dg)NM STAB,MWD,LWD,2 NM D.CLR,JARS,9.o.P.,ACCELERATORS,111 D.P..27 HWDP 09:00 AM BHA NO BHALENGTH DATE LAST INSPECTED: HOURS ON JARS: --m~¡~Ii!i~~I:IØORS~~'b1rII;~!JI:JlP.t:fASè!~~~.iYß~TJO~OM~~it.\.Umt1," 12:00 AM 12:30 AM 0.50 CASG Cuing and PJSM-tsG RUNNING Cemenllng easing and Cementing Casing and Cementing Ca.lng and Cementing easing and Cementing OtMr QttIer QttIer Other OtbIIr 0tMr Other Other 12:30 AM 04:30 AM 4.00 CASG CONT RlH WIr'CSG. 04:30 AM 01:00 AM 2.50 CIRC CIRC & CONDITlON MUD.AWAITING ARRIVAl OF VACUMN TRUCKS HELD UP BY MODUlE MOVE ON ICE ROAD. PRESS TEST UNES, PUMP SPACER, MIX AND PUMP 350 SX G W/ADDlTIVES,DISP W/RlG, BUMP PLUGS, FLOATS HELD. RIG DOWN CEMENTING HEAD & LANDING JT. 07:00 AM 01:00 AM 2.00 CEMENT 011:30 AM 0.50 CEMENT 01:30 AM 10:30 AM 01:00 PM 02:30 PM 03:00 PM 04:00 PM 10:30 PM 11:30 PM 10:30 AM 01:00 PM 02:30 PM 03:00 PM 04:00 PM 10:30 PM 11:30 PM 12:00 AM 1.00 2.50 1.50 0.50 1.00 6.50 1.00 0.50 CASG HOPE BOPE BOPE OTHER BKA RIGS TRIP_IN INSTALL PACKOFF,RlLDS & TEST TO 50001. CHANGE RAMS TO 3·112-. RIU & TEST UPPER & LOWER RAMS, FLOOR VALVES & DART VALVE. RIU & INSTALL WEAR BUSHING. CLEAR FLOOR OF 5- TOOLS & PIU 3·112- TOOLS. MIU BHA.r & RlH PIU D.P_ SUP & CUT DRlG UNE. PIU KELLY-INSTALL LoWER KELLY COCK-sAVERSUB & TORQUE ALL CONN. . 24.00 Supervisor. R.W. SPRlNGERO Daily Drilling Report: CD2-35 03130/98 Page 1 -~, --_....~ -,- ..,-,,--------- .----:--- '\ J .. ~. ARCa Alaska, Inc. ._____, ___. ___. ;~8?f' .1 ~~~1198 . .. ...__~_~_~__... _ _ ______I_:~~~~:~~~~___ _::_~~:~~_~VEst: 111 Well: CD2-35 Depth (MDnvD) 11149/7204 Prey Deplh MD: 9182 Contractor: DOYON Dally Cosl $ 141537 CUm Cost $ 231~35 Rig Name: DOYON 141 Last Csg: 7" @971S' Next C¡¡g: 4-112" liner Operation AI 0600: DRILLING HORIZONTAL. Upcoming OperaUons: DRILL HORIZONTAL TO r.D" &::œ.:.líJ»....mt¡':I_, ,- . . MUD TYPE E TH KCLPLY 9949 WEIGHT 9.2PPQ VISCOSITY 68sqc . PVNP 9/46 GELS 211 24 /25 APIWL 4.0 HTHP WL 12.8m1l3O min SOLIDS 6% HOLE VOLUME 304bbl MBT NA ph 8.1 LGS % PIT VOL '33 DAILY MUD $58122 TOTAL MUD $258895 COMPANY MI ~I ........-...-. .- 08:00 AM 10:30 AM 11:30AM ~lß};f 01:30 PM 04:00 PM 08:00 PM 09:00 PM 09:30 PM . 10:30 PM 11:30 PM ~ ROTwr 100 PUWT 125 sowr 95 AVG DRAG MAX ORAG TRO BTM 2500 TRQ OFF PUMP PR':$ 2950 III PUMP NO III LINER SZ 6111 SPM 1 65 III GPM2 273111 SPS 1 III SPP1 III MUD WT 9.2111 SIZE 6.125 MAKE CDP TYPE STR554 SERIAL NO 1902029 DEPTH OUT DEPTH IN 9182 FOOTAGE 167. ADT/AST / WOB2 RPM1 TFA , . ,;¡~..~ ~--~"'¡¡II"'I~"'Yf~il"W'liril"il , '\:', ,. ii~\\'~'"'ff'p"'i~!nlt~ ~r\_, 7:l1.V'1-'lti BIT NO. CI ENT N SIZE MAKE TYPE SERIAL NO DEPTH OUT DEPTH. IN FOOTAGE ADT/A$T / WOB2 RPM 1 TFA JETS JETS 121121141141 I I I I I I BIT COST BIT COST 0.00 DULL III GRADE III DULL III GRADE III EMPLOYER SPILL N TYPE VOLUME LAST SAFETY MTG 03131118 PRESSURE (psi) DIESEL VOL (bbl) o MUD VOL (bbl) sao WATER VOL (bbl) o TOTAL VOL (bbl) sao TOT FOR vÆLL (bbl) -".._-_.~ .._- .". ) Daily Drilling Report Rig Relase» hrs: Progress: 167 Est Cost To Date $ Shoe Test: 12.5 ppg E.M.W. LAST BOP/DIVERT LAST BOPIDRILL TST 02128/98 02128198 LAST H2S DRILL LAST FIRE DRILL LAst CONFINED LAST SPILL DRIl.l. SPACE FUEL USED 2845 480 WIND SPEEO 15 WIND DIRECTION 90· CHILL FACTOR ·F -58.12 AR.CO PERSONNEL 2 CONTRACTOR PERSONNEL MISCPERSONNEL 27 6 SERVICE PERSONNEL 14 TOTAL 49 6-118- PDC BIT,NAVlDRlLl MACH 1XL(AKo 1.20dg)NM STAB,MWD,LWD.2 NM D.ClR.JARS,9-D.P.,ACCELERATORS,111 D.P.,27 HWDP . 10:30 AM 11:30 AM 01:30 PM 04:00 PM 08:00 PM 09:00 PM 011:30 PM 10:30 PM 11:30 PM 12:00 AM 7. 1062.01 2.50 1.00 2.00 2.50 4.00 1.00 0.50 1.00 1.00 0.50 24.00 Daily Drilling Report: CD2-3S 03/31/98 DRlL DRIL CIRC Making Hole Making Hole Making Hole --_._--~_.~-_.~.-.._-----"'~._~_._.._-~_._--- CIRC DRlL PRB_DRLG TRIP_OUT Other Making Hole Maldng Hole Maldng Hole BHA NO BHA LENGTH DArE LAST INSPECTED: HOURS ON JARS: \'..~\Ì_'II'_"""___t"'_~Þ_~""\'II_IIIä''''''''''''''~'~IW'''''-'''~I'\II¡'''PI>'iW'''___.~~-' _all:!:b..;~Itil'A:l,'~i!ß.~ï!iII¡¡¡¡~ ,...'.......trnJ.:ßII.~I.~,..,..."...,'".f..,.,.v"~~.p~~~tIIM~.l.,,'.,If.,,,I',.~~".,..ßI.,. (LIf...."-II.-,,,~.. _, .~~~J!ØP'~~~,..r-~~~ 12:00 AM 12:30 AM 0.50 OTHER Other PJSM.PLANNED OPERA I NS·AWARENE55. 12:30 AM 01 :00 AM 0.50 RIGS Other RNISH HOOKING UP KELLY SPINNER. 01:00AM 01:30AM 0.50 BOPE other TEST LOWER & UPPER KELLY VALVES. 01 :30 AM 05:00 AM 3.50 TRIP IN Other RlH P/U D.P.. 05:00 AM 06:00 AM 1.00 REAM Making Hole WASH FI9420-9685'. 06:00 AM 08:00 AM 2.00 DRlL Making Hole DRILL CMT,FLOAT CLR & 5' CMT - TEST CSG TO 3500# ABOVE AND BELOW FLOAT CLR. DRILL HARD CMT, SHOE & l' RATHOLE W/CMTTO 9182'. DRILL FI9182·9802' ADT 1 HR. CIRC BTMS UP AND COND MUD FIF.I.T.PERFORM FIT TO 12.5ppg E.M.W.. DISPLACE MUD SYSTEM TO FLO-PRo(KCL POLYMER). DRLD FIt802·1Ii48' DIFFEREN11AL STICKING. JARRED FREE POH TO SHOE un 5 SINGLES. CIRC & CONDo BUILD 5 BBL CAC03 LCM PILL SPOT LCM PILL @ 9949' POH INTO SHOE- SQUEEZE 5 BBL PILL AWAY @ 200 PSI(.S ppg E.M.W. ADDITION) -.--.'_.~-_._.. --~-- ClRC Other CIRC CASG Other Other Page 1 ') .PHILLlPS Alaska, Inc. "m A Subsidiary of PHilLIPS PETROLEUM COMPANY TUBING CD2-35 (0-8777, 00:4.500, 10:3.958) .): HANGER (9590-9591, 00:4.500) PROOUCTION (0-9775, 00:7.000, Wt:26.00) LINER SLOTTED (9870-10629, 00:4.500) ..~ ~r --3i . LINER (10629-10693, 00:4.500) I · I I I I ~:; I i I. '.'.... ! . ~ ~~ i . I · I I I 1 ¡ . ;~;!t . ;;',,···\·..<t .... LINER SLaTTER (10693-11609, 00:4.500) LINER (11609-11642, 00:4.500) SHOE (11642-11643, 00:4.500) ) ALPINE CD2-35 API: 501032025600 SSSV Type: WRDP Annular Fluid: Well Type: PROD Orig Completion: Last W/O: Angle @ TS: deg @ Angle @ TO: 91 deg @ 11984 Rev Reason: New Schematic by ImO Last Update: 7/5/2001 Ref Log Date: TD: 11984 ftKB Max Hole Angle: 96 deg @ 9477 Reference Log: Last Tag: Last Tag Date: CasingString-ALL STRINGS Description I Size CONDUCTOR 16.000 SURFACE 9.625 PRODUCTION 7.000 PROD LINER 4.500 OPEN HOLE 6.125 Tubing String - TUBING Size I Top 4.500 0 Gas Lift MandrelsNalves St MD TVD Man Mfr 3703 3395 CAMCO Top o o o 9590 9775 Bottom TVD Wt Grade Thread 109 109 0,00 3326 3120 40.00 L-80 BTC 9775 7200 26.00 L-80 BTC-MOD 11643 7133 2.99 11984 11984 4.50 Wt I Grade I 12.60 L-80 Thread IBT MOD Bottom 8777 TVD 7031 V Type VOD Latch Port TRO DMY 1.0 BTM 0.000 0 DMY 1.0 BTM 0.000 0 DMY 1,0 BTM 0.000 0 Date Run 12/9/1999 12/9/1999 Vlv Cmnt VMfr Man Type KBG-2LS MOD 2 6215 5200 CAMCO KBG-2LS MOD 3 8534 6854 CAMCO KBG-2LS MOD Other (Jlugs, equip., etc.)-JEWELRY Depth TVD Type 515 515 NIP 515 515 SSSV 8624 6920 NIP 8676 6958 PKR 8676 6958 SEAL 12/9/1999 ID 3.812 2.125 3.813 3.875 0.000 8765 7023 8777 7031 9590 7210 9591 7210 9870 7202 10629 7184 10693 7180 NIP WLEG HANGER LINER LINER SLOTTED LINER LINER SLOTTER LINER SHOE Description CAMCO BP-6i SSSV NIPPLE IN DB6 LOCK WRDP-2 SSSV w/single .25" x 0.049" s/s control line MODEL X LANDING NIPPLE BAKER SABL-3 PACKER KBH-22 ANCHOR SEAL ASSEMBLY (no OD or ID size listed in paperwork, check later) HES 'XN' NIPPLE 3.725 3.958 3.958 3.958 3.958 BAER ZXP-HMC LINER HANGER 3.958 3.958 3.958 3.958 11609 7134 11642 7133 General Notes Date I Note 7/5/2001 THIS SCHEMATIC WAS BUILT FROM "PROPOSED WELL COMPLETION" DRAWING DATED 12/9/1999 :f ,þo ) ) ¿;¡D/-~)~ Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 "~ November 27, 2001 Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, Alaska, 99501 Re: Application for Sundry Approval-Temporary Shutdown of Drilling Operations CD2-45 Dear Sir or Madam: Phillips Alaska, Inc. hereby applies for Sundry Approval to temporarily shutdown drilling operations on well CD2-45 with Doyon rig 19, at Alpine. Drilling will be resumed on CD2-45 in approximately 30 days. It is intended to move the rig off CD2-45 in order to drill the production interval on CD2- 47 with oil based mud. The effect of oil based mud on the Alpine sand is being tested on CD2-47 and CD2-45. Severe losses were encountered on CD2-45 shortly after drilling ahead with oil based mud. The losses are thought to be caused by faulting/fracture in the Alpine. There is a limited volume of oil based mud available at Alpine, and conventional lost circulation control methods have not worked; so it was decided to temporarily shut down drilling operations on CD2-45. The oil based mud test will be continued on CD2-47 prior to storing or disposing of the excess oil based mud. Please find attached Form 10-403, Application for Sundry Approvals, and the proposed program for securing the well. If you have any questions or require further information, please contact Vern Johnson at 265-6081 or Chip Alvord at 265-6120. ~inc Iy, ..:.-- ~, ,,/.. 7/_/ ern Johnson Drilling Engineer RECEIVED NOV 2 8 2001 Attachments cc: CD2-45 Well File / Sharon Allsup Drake Chip Alvord Cliff Crabtree Meg Kremer Nancy Lambert Lanston Chin Alaska 011 & Gas Cons. Commission Anchorage ATO 1530 A TO 868 ATO 848 ATO 844 Anadarko - Houston Kuukpik Corporation e-mail : Tommy_Thompson @anadarko.com ORIGINAL ) ) -~~-o~\1 STATE OF ALASKA t~,'Ij "" J'G ALASKA OIL AND GAS CONSERVATION COMMISSION ~. . APPLICATION FOR SUNDRY APPROVALS (j 1. Type of request: Abandon Suspend _ Alter casing _ Repair well _ Change approved program _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2013' FNL, 1509' FEL, Sec. 2, T11 N, R4E, UM At top of productive interval 612' FSL, 1098' FEL, Sec. 1, T11 N, R4E, U M At effective depth At total depth 2043' FNL, 316' FWL, Sec. 7, T11 N, R5E, UM 12. Present well condition summary Total depth: measured true vertical 10038 7168 10038 7168 Effective depth: measu red true ve rtical Casing Conductor Surface Length 77' 2727' Size 16" 9-5/8" Production 9935' 7" Perforation depth: measu red None true vertical None Operational shutdown _X Plugging _ Pull tubing _ 5. Type of Well: Development _X Exploratory __ Stratigraphic _ Service - -- Re-enter suspended well _ Time extension Stimulate Variance Perforate 6. Datum elevation (OF or KB feet) RKB 52 feet 7. Unit or Property name Other Colville River Un it 8. Well number CD2-45 9. Permit number / approval number 201-212 10. API number 50-1 03-20395-00 11. Field / Pool m__ Per APD Colville River Field / Alpine Oil Pool Detailed operations program _X Approved by order of the Commission Original Sìgned b· Cammy 09I::h~" ----- Per APD feet Plugs (measured) feet feet Junk (measured) feet Cemented 270 SX AS1 389 Sx AS III L & 237 Sx 15.8 class G 165 Sx 15.8 class G ORiGiNAL Measured Depth 114' 2764' True vertical Depth 114' 2389' 9972' 7167' RECEIVED NOV 2 8 2001 Tubing (size, grade, and measured depth 4.5" 12.6#, L-80 @ +/-2300' MD (Planned circulation string) Alaska 011 & Gas Cons. Commission Anchorage 14. Estimated date for commencing operation 15. Status of well classification as: November 27,2001 16. If proposal was verbally approved Oil _X Gas I ///1 \ 1/ ~~/C) I ~.... /'(4" "t:I~V'" j/';¡ . Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIgned A-c.. e.. nJ) Title: Alpine Drilling Team Leader . Chip Alvord L..A' '- FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity _ BOP Test Location clearance Mechanical Integrity Test _ Subsequent form required 10- Packers & SSSV (type & measured depth) 13. Attachments Description summary of proposal _ I Form 10-403 Rev 06/15/88· BOP sketch Suspended _ Questions? Call Vern Johnson 265-6081 Date " /1.. 7 (o r I Approv~! no. '- -«) \ - ,-~30 ~C)~ 'Ù~ ~\\,()~\\(:)~ C{.~\\ ,",c-\-'\c...9: Ò~~\~ ~~~~ Commissioner Date /i/.-1:JØ J SUBMIT IN TRIPLICATE ) ) CD2-45 Suspension Procedure: 1. Spot a 20-30 ppb LCM pill on bottom. 2. Pull out of hole, lay down BRA. 3. RU Schlumberger wireline. 4. PU and Rill with 6" Gauge Ring! Junk Basket. Run the GR/JB as deep as the tool will fall. 5. PU and run Baker retrievable packer on wireline. 6. Set packer at +/-9100' MD. 7. Pull out of hole with setting tool. 8. Pressure test casing and bridge plug to 3500 psi for 30 min. 9. Rig down Schlumberger wireline. 10. Run in hole with open ended drill pipe to +/- 10' above the bridge plug. 11. Displace to 9.6 ppg KCl brine as follows: 12. Run in hole with 4-1/2" 12.6# ffiT-M tubing to +/- 2300' MD. 13. Displace tubing and annulus to diesel freeze protect. 14. Make up the tubing hanger to the last joint of tubing and roughly orient tubing string so that the hanger matches up with the centering guide in the tubing bowl. 15. Make up the landing joint-(A) with integral isolation sleeve. Drain and flush the BOP stack and the tubing head bowl. Land the tubing hanger and run in all the lock down screws. 16. Back out and recover landing joint-(A). Install the 2-way check (in the lowermost Cameron profile in the wellhead) by dry-rodding through the BOP stack. P/U the landing joint-(B) and MlU to the tubing hanger. Then internally pressure test the hanger seals to 5000 psi. Remove the landing joint. 17. Nipple down the BOP stack. 18. Install the wellhead adapter assembly. Pressure test the wellhead adapter assembly to 5000 psi. Remove the 2-way check with the FMC lubricator. 19. Shut in the well on both the tubing and annulus sides. R/U the FMC lubricator and install the BPV in the lower 'Cameron' profile. Ensure all surface valves are in the closed position. 20. RDMO Doyon 19. ) ~~ ~~E : f ~~~~~~~ ALASKA. OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Drilling Team Manager Phillips Alaska, Inc. , PO Box 100360 Anchorage AK 99510 Re: Colville River Unit CD2-45 Phillips Alaska, Inc. Permit No: 201-212 Sur Loc: 2013' FNL, 1509' FEL, Sec 2, TUN, R4E, UM Btmhole Lac. 2034' FNL, 316' FWL, Sec. 7, TUN, R5E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission for approval on form 10-403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on CD2 must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ~()t¿LL 1y; C~; -OJdhsli Taylor Chair BY ORDER OF THE COMMISSION DATED this 7th day of November, 2001 jjclEnclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation wlo encl. ... ') 1a. Type of Work STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1b Type of Well Exploratory Service Development Gas Drill X Re-Entry Name of Operator Phillips Alaska, Inc. Address Redrill ) \'J\ k\' ~ . tv I \\llo tu; ç ~-èr, 5. Datum Elevation (OF or KB) DF 52' 6. Property Designation ADL 380075 & ADL 25559 7. Unit or property Name Stratigraphic Test Development Oil X Single Zone X Multiple Zone 10. Field and Pool Colville River Field Alpine Oil Pool Deepen 2. 3. 4. P. O. Box 100360, Anchorage, AK 99510-0360 Location of well at surface 2013' FNL, 1509' FEL, Sec. 2, T11 N, R4E, UM At target (=7" casing point) 612' FSL, 1098' FEL, Sec. 1, T11 N, R4E, UM At total depth 2034' FNL, 316' FWL, Sec. 7, T11N, R5E, UM 12. Distance to nearest 13. Distance to nearest well Property line CD2-42 Crosses from feet 29.5' at 288' MD T11 N R4E to T11 N R5E 16. To be completed for deviated wells Colville River Unit 8. Well number CD2-45 9. Approximate spud date 11/14/2001 14. Number of acres in property Feet 2560 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) feet 11. Type Bond (see 20 AAC 25.025) Statewide Number #59-52-180 Amount $200,000 15. Proposed depth (MD and TVD) 12906 7168 TVD feet Kickoff depth 250' feet Maximum hole angle 90.21 Maximum surface 2527 psig At total depth (TV D) 3221 at psig 7118' TVD.SS 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 42" 16" 62.5# H-40 Weld 77' 37' 37' 114' 114' 270 Sx Arctic set 1 12.25" 9.625" 36# J-55 BTC 2763' 37' 37' 2800' 2400' 531 Sx Arcticset III L & 230 Sx Class G 8.5" 7" 26# L-80 BTC-M 9868' 37' 37' 9905' 7170' 137 Sx Class G N/A 4.5" 12.6# L-80 IBT-mod 9386' 32' 32' 9423" 7047' Tubing OCT 3 0 2001 by order o~ .. Alaska Oil & Qa~(_ ri'š"r'. ~",.J. the commiSSion Date ~n( ...... r ~I~O 1 o ~ I G / Nt : G W;rtnpl;care 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet true vertical feet Plugs (measured) Effective depth: measured true vertical feet feet Junk (measured) Casing Length Size Cemented Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee X Property plat Drilling fluid program X Time vs depth plot BOP Sketch Refraction analysis Diverter Sketch Seabed report 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ \. t¡,~'-'~ Title 'u__~ __ - I Commission Use Only Permit NU~n .-- 2J 2- I ~b.1 nï~e3 -- 203'ty C;l.-:> I Approval date \ \ \ \ \ 0 \ Conditions of approval Samples required Yes ~;: Mud log reqUire~ Hydrogen sulfide measures Yes 8 .- Directional survey required ð Required working pressure for BOPE 2M 3M 5M 10M 15M Other: ~ 5"0 G? ~ \ ""- '\ f'..\ ~\,;:) \V\.. ~~ \> ~c:;. ~ Original Sìgned By C-v Oechsli Drilling Team Leader Approved by Form 10-401 Rev. 7-24-89 Commissioner Measured depth True Vertical depth Drilling program X 20 AAC 25.050 requirements X Date l 0/2- c¡ /0 ( I See cover letter for Other requirements Yes No e~ HI::CEIVED ) ) CD2-45 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) .12-1/4" Hole /9-5/8" CasinQ Interval Event Risk Level Conductor Broach Low Well Collision Low Gas Hydrates Low Running Sands and Gravel Low Abnormal Pressure in Surface Formations >2000' TVD Lost Circulation Low Low 8-1/2" Hole /7" CasinQ Interval Event Risk Level Abnormal Pressure in low Surface Formations >2000' TVD Lost circulation Low Hole swabbing on trips Moderate Abnormal Reservoir Pressure low Hydrogen Sulfide gas Low M itiqation Strateqy Monitor cellar continuously during interval. Gyro single shots as required Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud temperatures Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Diverter drills, increased mud weight Reduced pump rates, mud rheology, lost circulation material, use of low density cement slurries M itiqation Strateqy BOPE drills, Keep mud weight above 10.4 ppg. Check for flow during connections and if needed, increase mud weight. Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. Well control drills, increased mud weight. No mapped faults occur within 700' of the planned wellbore. H2S drills, detection systems, alarms, standard well control practices, mud scavengers .6-1/8" Hole / Horizontal Production Hole Event Risk Level Lost circulation Low Hole swabbing on trips Moderate Abnormal Reservoir Pressure Medium Hydrogen Sulfide gas Low M itiqation Strateqy Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. BOPE drills, Keep mud weight above 9.3 ppg. Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud weight. H2S drills, detection systems, alarms, standard well control practices, mud scavengers o iiGiNA:~ ) Alpine: CD2-45 Procedure 1. Install diverter. Move on Doyon 19. Function test diverter. 2. Drill 12 %" hole to the surface casing point as per the directional plan. 3. Run and cement 9 5/8" surface casing. 4. Install and test BOPE to minimum 5000 psi. 5. Pressure test casing to 2500 psi. 6. Drill out 20' of new hole. Perform leak off test. 7. Drill 8 %" hole to the intermediate casing point in the Alpine Sand. 8. Run and cement 7" casing as per program. Top of cement + 500 feet MD above Alpine reservoir. Carry out a leak off test down the 9-5/8" x 1'1 casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus. 1. Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.5 ppg EMW. 2. Drill 6-1/8" horizontal section to well TD with mineral based oil based mud. 3. Contingency - set open hole isolation equipment if required (due to unconsolidated formation or wellbore having moved out of the Alpine reservoir sand). 9. Circulate and condition mud and pull out of hole. 10. Run 4-Y2", 12.6 #, L-80 tubing with SSSV nipple, gas lift mandrels, sliding sleeve and production packer. Land hanger. 11. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 12. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 13. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. 14. Rig up lubricator and slick line and shift sliding sleeve. 15. Circulate tubing and annulus to diesel and install freeze protection in the annulus. 16. Run in with slickline and close sliding sleeve. 17. Set BPV and secure well. Move rig off. OF'G,AA~ ') ) Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD2-42 will be the closest well to CD2-45, 30' at 288' MD. Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 27' at 3381 MD. DrillinQ Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Alpine reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material has proved effective in dealing with lost circulation in previous development wells. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular PumpinQ Operations: Incidental fluids developed from drilling operations on well CD2-45 will be injected into a permitted annulus on CD2 pad or the class 2 disposal well on CD1 pad. Incidental fluids to include oil based mud using mineral oil as the base fluid. The CD2-45 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 20001 TVD. The only significant hydrocarbon zone is the Alpine reservoir and there will be 500' of cement fill above the top of the Alpine as per regulations. We request that CD2-45 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set below the base of the Schrader Bluff Formation (C-30). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2400') + 1,500 psi = 2,998 psi Pore Pressure = 1,086 psi Therefore Differential = 2998 - 1086 = 1912 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 850/0 collapse and burst ratings listed in the following table: Wt Connection 850/0 of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 36 J-55 3 BTC 2,020 psi 1,717 psi 3,520 psi 2,992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi O F- 1 . .I 1 j' U I (v J-, L ') ) CD2-45 DRILLING FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point - 8 Y2" Section - 6 1 /8" point -12 %" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.2 ppg PV 1 0 - 25 15 -20 YP 20 - 60 15 - 25 18 -25 Funnel Viscosity 100 - 200 Initial Gels 4-8 NA 10 minute gels <18 9-12 API Filtrate NC - 10 cc 1 30 min 4 - 12 cc/30 min (drilling) NA HPHT Fluid Loss at 160 4.0-5.5 PH 8.5 -9.0 9.0 -10.0 NA Electrical Stability +800Vts Oil Iwater ratio 80/20 Surface Hole: A standard high viscosity fresh water 1 gel spud mud is recommended for the surface interval. Keep flowline viscosity at ± 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel 1 polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the Alpine is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. Production Hole Section : The horizontal production interval will be drilled with a 80/20 oil/water ratio M-I Versa-Pro mineral oil based drill-in fluid. The base fluid will consist of high flash point (>200 F) mineral oil with 25% by weight calcium chloride as the internal phase. Calcium carbonate bridging material will be added to minimize formation damage. o ;'G^'A~ ) ') Colville River Field CD2-45 Production Well Completion Plan J" a '...........'............... : L. ,- :',...1 1111t I 11.:.;;.·....1 cI.%.!.I. t lil,.·~.... . lIf ~è1 ......( mm ¡¡I¡II! 4- ::" ::::~:~:_~ 1:~sv Nipple (3.812" ID) at 2000' TVD=2933':Ddated 1 0/27/01 lillill ~~~~t~~~'~~~~:9~i~sDc~~r~~~~Zs Lock (3.812' aD) run in profile ¡¡¡¡m 9-5/8" 36 ppf J-55 BTC _ Surface Casing @ 2800' MD I 2400' TVD cemented to surface J Cameo KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK-2 Lateh WRDP-2 SSSV (2.125"ID) wI DB-6 No-Go Lock (3.812" OD) - to be installed later Packer Fluid mix: 9.6 PPQ KCI Brine with 2000' TVD diesel cap Tubing Supended with diesel to lowest GLM Completion MD TVD Tubing Hanger 32' 32' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco BAL-O SSSV Nipple 2236' 2000" End thermal centralizers 2800' 2400' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 4209' 3400' 4-1/2", 12.6#/ft, IBT-Mod Tubing Start thermal centralizers. 5760' 4500' (1 per joint) Camco KBG-2 GLM (3.909" ID) 7451' 5700' 4-1/2", 12.6#/ft, IBT-Mod Tubing Baker 4-1/2" CMD sliding sleeve 9145' 6896' with 3.813 'X' Profile 4-1/2" tubing joints (2) HES "X" (3.813" ID) 9245' 6956' 4-1/2" tubing joint (1) Baker 53 Packer 9300' 6987' 4-1/2" tubing joints (2) HES "XN" (3.725" ID)-62.9º inc 9412' 7042' 4-1/2" 10' pup joint WEG 9423' 7047' 4-1/2" 12.6 ppf L-80 IBT Mod. R3 tubing run with Jet Lube Run'n'Seal pipe dope Start thermal centralizers. 1 per joint from 4500' TVD to 2400' TVD Cameo KBG-2 GLM (3.909" ID) at 5700' TVD for E Dummy with 1" BK-2 Lateh Baker 4-1/2" CMD sliding sleeve with 3.813 'X' Profile set 2 joints above the X landing nipple ¡~::ffi;¡~iIr¡~ker 53 Packer at +1- 9300' ":::: ~ ;nn~~~j~j~jn~j~~~j::;.¡¡ . . ~ . . . , . ~-_._----------------------------------------------------, Well TD at ¡ 12906' MD I i '." .. . 7168' TVD ¡ Top Alpine C at 9718' MD I 7145' TVD ·~~·:·~<!J.UWJJlUlU"U1L!r-----------------------------------------------------------" TOC @ +/- 9118' MD (600' MD above top Alpine C) 7" 26 ppf L-80 BTC Mod Production Casing @ 9905' MD I 7170' TVD @ 87º o = 'G ~.j- ) ) Colville River Field CD2-45 Production Well Completion Plan Formation Isolation Contingency Options J"" mw mm: 16" Conductor to 114' 4-1/2" Camco BAL-O SSSV Nipple (3.812" 10), WRDP-2 SSSV (2.25" ID) and DB-6 No-Go Lock (3.812" OD) with dual 1/4" x 0.049" sls control line @ 2000' TVD 9-5/8" 36 ppf J-55 BTC IŒ Surface Casing @ 2800' MD I 2400' TVD cemented to surface . If I' I' 11 ::,* t ,::1\ Cameo KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK-2 Latch II 4-1/2" 12.6 ppf L-80 IBT Mod. R3 tubing run with Jet Lube Run'n'Seal pipe dope Start thermal centralizers. 1 per joint from 4500' TVD to 2400' TVD Cameo KBG-2 GLM (3.909" ID) at 5700' TVD for E Dummy with 1" BK-2 Latch Baker 4-1/2" CMD sliding sleeve with 3.813 'X' Profile set 2 joints above the X landing nipple Baker 83 Packer set at +/- 9300' MD TOC @ +/- 9118' MD (600' MD above top Alpine C) Updated 10/27/01 (A) Bonzai ECP Assemblv - Baker ZXP Packer (4.75" 10) - Baker HMC Liner Hanger - XO to 1ST-Mod - blank 4-1/2" joints (TBD) - Cementing Valve - Baker Payzone ECP (mud inflated) -Landing Collar - 4-1/2" joint (1- 2) blank - Guide Shoe (B) Open Hole Scab Liner - Baker Payzone ECP (cement inflated) - 4-1/2" joints (TSD) blank tbg - Baker Payzone ECP (cement inflated) - Baker Model XL-10 ECP (anchor) - Muleshoe I Entry Guide (C) Open Hole BridQe Pluq Assemblv - Baker Payzone ECP (cement inflated) -XO -Float Collar - 4-1/2" Float Shoe Well TD at 12906' MD I 7168' TVD 7" 26 ppf L -80 BTC Mod Production Casing @ 9905' MD I 7170' TVD @ 87º 0: G N.4l. ) ') CD2-45 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c ) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size Csg Setting Fracture Pore pressure ASP Drilling (in) Depth Gradient (Ibs. I (psi) (psi) MDfTVD(ft) gal) 16 114/114 10.9 52 53 9 5/8 2800/2400 14.2 1086 1569 7" 9905 I 7170 16.0 3244 2527 N/A 12906 I 7168 16.0 3244 N/A · NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to minimum 3500 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in Ib/gal 0.052 = Conversion from Ib./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP - (0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1} D = [(10.9 x 0.052) - 0.1] x 114 = 53 psi OR ASP = FPP - (0.1 x D) = 1086 - (0.1 x 2400') = 846 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1] D = [(14.2 x 0.052) - 0.1] x 2400 = 1532 psi OR ASP = FPP - (0.1 x D) = 3244 - (0.1 x 7170') = 2527 psi 3. Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3244 - (0.1 x 7168') = 2527 psi 0: ,'G, NJ. 1_ ) ) Alpine. CD2-45 Well Cementing Requirements 95/8" Surface Casing run to 2800' MD /2400' TVD. Cement from 2800' MD to 2300' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2300' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 500/0 excess below the permafrost. Lead slurry: System: Tail slurry: System: (23001-1629') X 0.3132 fe/ft X 1.5 (50% excess) = 315.2 fe below permafrost 1629' X 0.3132 fe/ft X 4 (300% excess) = 2040.8 fe above permafrost Total volume = 315.2 + 2040.8 = 2356.0 fe => 531 Sx @ 4.44 fe/sk 531 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 fe/sk, Class G + 30% 0053 thixotropic additive, 0.6% 0046 antifoamer, 1.5% 0079 extender, 1.5% S001 accelerator, 50% 0124 extender and 9% BWOW1 0044 freeze suppressant 500' X 0.3132 fe/ft X 1.5 (50% excess) = 234.9 fe annular volume 80' X 0.4341 fe/ft = 34.7 fe shoe joint volume Total volume = 234.9 + 34.7 = 269.6 fe => 230 Sx @ 1.17 ft3/sk 230 Sx Class G + 0.2% 0046 antifoamer, 0.3% 0065 dispersant and 1 % S001 accelerator @ 15.8 PPG yielding 1.17 fe/sk 7" Intermediate Casing run to 9905' MD /7170' TVD Cement from 9905' MO to +/- 9118' MD (minimum 600' MO above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: System: (9905' - 9118') X 0.1268 fe/ft X 1.4 (40% excess) = 139.7 fe annular volume 80' X 0.2148 fe/ft = 17.2 fe shoe joint volume Total volume = 139.7 + 17.2 = 156.9 fe => 137 Sx @ 1.15 fe/sk 137 Sx Class G + 0.2% 0046 antifoamer, 0.25% 0065 dispersant, 0.25% 0800 retarder and 0.18% 0167 fluid loss additive @ 15.8 PPG yielding 1.15 fe/sk 1 By Weight Of mix Water, all other additives are BWOCement O::'G NA_ f)o¡ Rcfr:rc'1c(; :s CJ2~/"5 Vers:on#6. Structure : CO#2 Field : Alpine Field Well: 45 - - '\ PHILLIPS l 0 ----- - _~--Î Created oy """chee For: V Johnson Dc:c c:oucd : i g-Oct-20Qi Pl~illilDS Alaska, II1CÐ Coord:~u~cs erc in 'ce. reference s~ot #LS. Location : North Slope. : r...¡c Ver~icc. Jep:ns ere rcfcrc~cc RKB(Doyon i 9). ---.- -" ÐAIt~ :~~ INTE(j PROÞ! L~ "11M M ¡NT DATA ~ ~ ~ ~ r ~ ! ~ ~ ~ ~ ¡ ¡ i I vUe [ i ! Point ----- MD inc Dir TVD No rt h East V. Sect Oeg/ ~ 00 "--- I(C:-) 250.00 0.00 102.50 250.00 0.00 0.00 0.00 0.00 '3eg:r fTd/:LJrn R: LOO.OO 3.00 102.50 399.93 -0.85 3.83 3.83 2.00 :3cg 3/~00 B!d/; :0 Lf ~ 765.90 10.00 ~ 25.00 763.30 -21.17 39.25 44.52 2.00 Wes: Sck i 078.05 19.27 ¡19.41 1065.00 -62.10 106.4 7 122.73 3.00 Jose ~)e(;nc)~ros~ 1628.60 35.56 '1 ! 3.85 í 552.00 -î74.69 332.69 375.34 3.00 : °nr' 1940.15 44.80 -: î : .68 1789.78 ~252.04 517.97 575.95 3.00 \..1 \....... C 1:0 2552. í 3 4L.80 î í .68 2224.00 -4î1.35 918.70 1006.47 0.00 C---50 2795.95 44.80 1 í ! .68 2397.00 -474.82 í 078.36 1178.00 0.00 9 5/8 Casing Pt 2800. í 8 44.80 í 1 í .68 2400.00 -475.92 1 08 í . í 3 í í 80.98 0.00 C---/O 3268.09 44.80 1 î í .68 2732.00 -597.73 í 387.53 1510.î5 0.00 1(" .3 4831.09 44.80 1 1 1. 68 3841.00 -1004.62 2411.02 2609.72 0.00 K" 7 5135.52 44.80 í î î .68 4057.00 -1083.87 2610.37 2823.88 0.00 Aüicn 97 7397.57 44.80 1 1 í .68 5662.00 -1672.74 4091 .61 44 í 5.23 0.00 Aibic': --96 8028.97 44.80 í í -: .68 6110.00 -1837.11 4505.07 4859.42 0.00 rRZ 891 1.25 44.80 í 1 1 .68 6736.00 -2066.79 5082.80 54.80. í 0 0.00 - [jcgin Fni ß!d/Trn 8990. í 0 44.80 í 1 í .68 6791.95 -2087.32 5134.44 5535.57 0.00 K -- 1 9187.19 52.74 123.38 6922.00 -2156.36 5264.93 5683.02 6.00 ~CU 9353.62 60.18 í 31 .39 7014.00 -2240.74 5374.68 5818.14 6.00 M;luveach ^ 9559.93 69.95 í 39.78 7101.00 -2374.42 5504.90 5992.64 6.00 <:::) Ap:ne 'ì 9626.35 73.18 í 42.24 7122.00 -2423.39 5544.53 6049.25 6.00 LJ ::0 Np;nc C 9717.79 77.68 í 45.49 7145.00 -2494.86 5596.68 6'126.71 6.00 ---- orgCl Csg pc 9905.34 87.00 í 51 .86 7170.00 -2653.43 5693.07 628 í .06 6.00 l ~ ;oc í 0226.35 90.21 í 5 ¡ .86 7i77.81 -2936.37 5844.40 6537.75 ¡ .00 ---- . í..... -- r' !; ~ ~ 2905.82 90.21 ~ 5 ~ .86 7 i 68.00 -5299.11 7108.1 8681 .30 0.00 ---. 11.1 \., S CJ c:::: ~ r--- ~ 400 ~ 800 1200 1600 2000 If) 0 C 2LOO -+ :::r ,..---.,. -h 2800 CD ~ '--" I V !D - Csg P¡ ~ TD LOCATION: 2034' FNL, 3í 6' FWL. SEC. 7, Tí ~ N, R5E TRUE r' c$) 6, rlR~e~~: Fn! 8:d/Trn LCU Miiuvecch A AÄI~l;e DC \\'\..TOrget - Csg Pi TARGET LOCATION: 6,2' FSL. ,098' FEL SEC. 1, T1 íN. R4E 114.99 AZIMUTH 6281' (TO TARGET) ",""Plane of Proposal""''' ~, A!bicn-97 ~ A:bian-96 111'ß{J dZ K-3 K-2 C-LO ~35~8 Ccs:"'c P. C-20 J SvR""ACE L.OCATIOi\: 2~~r i:\1\~~9~Ir- '<C:1cc:~ ;rd[Ù~ i< 10 G~'3éq ~LOO '3dl-r'1 eft <.50 Vies, Sc~ 1\2 :1cs~óër~c~ros~ _ ____1_--1-_ 1600 2000 2400 2800 3200 3600 LOOO 4400 L800 5200 5600 6000 6400 6800 7200 7600 8000 8400 8800 9200 ~ ~ ~ -""="~~....... -- ------ ~...... - - {PHILLIPS? \ East (feet) -> ( Location Structure: CO#2 Field : Alpine Field PI~illi 1) S 1;>00 800 408 Crcated by b"TJ¡c;~cc: For: V Johnson Cote p'ottcd : í9-Ocl-200~ í~rot Re~crerJcc is CD2-/..S Vcrs:or¡#6. Coorc::r.otcs arc ~n feet re~efer'ce s!ot 145. ~ruc Vcrfco: Deot'1s erc reference Rr<3(DoY0119). B^kU H\KI!£S INTt:Q C ::0 ---- ~ ---- ~ ~ ~~. r=-- ) ) ]It) 11 i 1 Jil i JP s Al a s Jk a, ][ 11 C . Crooled hy bmic:hoel For: V Johnson Dole plol\c:d : ??-Oel--?OOI Plot r'<Jforcnco is CD::?-45 Vorsiontl7. Coordinatos <JrO in fact roforonco slo{ #45. Vertical DcptllS ara reference iì1:f,\¡C, U¡¡'~Ii1íð: šRr..t:~!: ¡¡:m¡o-- 400 -. 800 .- 1200 - 1600 - 2000 - 2400· ,...-.,. (j) Q) 2800 - ........" ...c õ.. 3700 Q) 0 0 3600 Ü +- I.- Q) 4·DOO· > Q) ::::J 4400 - l.- f-- I V 4800· 5700 - :'600 6000 Structure: CD/12 Field: Alpine Field Well: 45 Location: North Slope, Î KOI~ 2.00 Begin Bid/Turn Rl . 4.82 6.74 8./0 11.00 Bog 3/100 Gld/Trn Lft 13.9/ 16.94· 19.92 Wost Sak 22.91 25.88 28.81 31 X~ 1 DI_S: 3.00 deg pcr 100 fl 3 .7 [30so I"crmafrosl 40.64 mc Dl.S: 2.00 deg per 100 fl DIS: :5.00 dog per 100 ft 114.99 AZIMUTH 6281' (TO TARGET) ...Plano of Proposal'" C-4·0 Casing I'l C··20 TANGENT ANGLE 4-1-.80 DEG ..,j K·-7. 6'<00 . 6800 - Di S: 6.00 cog por : 00 ~l noD -i /E~)O --:- - ----------~-- ----- ---..- -,--.~--- -~---'.- .~-_._-'--' . ,,~"'--,-".._.. '600 ;;000 2~OO :7800 J70C JGOO '<dad u.oo ~80C j20C j600 600e 6~00 6800 I. DC . 200 800 Vert i c a I Sect ion (f e e t) - > Azimuth 114.99 with reference 0.00 N, 0.00 E from slot /145 TAHGE'r ANGLE 87 DEG ^lbian-96 HR! l30gin r-~I 13ld/Trn K -- ~ I_C,j 67.33 ¡'¡!~!~Ç~gl-b^ 76 80 ---'::'^lp:~cL . ~\:'J- -.-~) csq ,0" ío(qe\ - o ~/GliVAL 8200 ~/ -- 8000 145 ¡ TO - Csg pt 7800 7600 _.x=-~~~~ ILUPS ( \ ",\ -'¡ 7LOO Vertico I Section (feet) - > Azimuth 151.86 with reference 0.00 N, 0.00 E from slot #45 7200 7000 6800 6400 6600 FINAL ANGLE 90.21 DEG 6200 6000 5400 5600 5800 EOC 5200 5000 DLS: 6.00 deg oer 100 ft TARGET ANGLE 87 DEG *xxP:cne of ?roposci**"" 151.86 AZIMUTH 5025' (TO TARGET) Location North Slope, Alaska Well 45 Structure : CD#2 Field : Alpine Field Alasl,(a, IT1C. Dnl l~lT,l;TD' S .1 I .1Ll h L800 4600 1,400 /.200 /.000 l..CU HRZ Beg¡~ Fnl Bid/'r'" eAA¡¡~ H1..'&Ç..~ ¡;"'IH..} PiO~ f<c"crCf1ce :5 CD2 -"'~5 Vers:o~#6. COOfC;.,ctcs ere ;r. feet 'cfefe~ce s~ot #45. True Vcrt:cc! JCP:"s me 'c"c,.c~cc RKS{DoY0>1¡ 9). C'CO:CC by om:c!'ac' For: V Johnson Jc:e ootrcc:: : ;g-Oc:-200'i .\800 /6CO I V /I.CO ·1 Q) ::J L f- noD -+- L Q) > /COO' o o ..c -+- Q. Q) 68CO o 66CO r--.. -+- Q) Q) '+- '-" 1)1.00 C) ::x:J ---- ~ --- ==:: ~ r-- , i " ~ í 80 .~~ ~~ 200 - 160 í40 "- " "- " "- "- "- 5' I ~ , , 00 I 20 flÐl - 0 - 20 40 (J) 0 60 C .1500 -+- :r 80 r---. -+. CD CD -+- '---" 100 I V 120 - 40 380 400 3¿0 360 320 - __ 1500 Qb~ '...2700 "- "- flÐ 300 280 1500 260 \3 .. '500 ~~ ~100 . 1300 . ~ 100 1900. J( ¡ -;00 "': 300 ""'-~..~ "- " >",2500 '-~,-...,- ........, , "- "" .. íi'QO -',<.1300 . í300 ..... ';'-'" 230~" . '500 ~, . '100 '~,J1 00 ¡ 100 ','" "" ~ 240 220 East (feet) -> í 50 '80 200 ,40 Location North Slope, Structure : CO#2 Field : Alpine Field Well: 45 Incê Pllilli 10 S Al"sKi' a ·d " , ;>0 0 ;>0 40 . &':~o~l~,% · 100 9ðo '~ ,E9 iSg 0 1 500:' -~/?O ,.A~300 . . 100 2'ÒO'~:",,,- ""0' '0' . 500 . "- ", .' , . S 300 " ~~ 000 s 3.00 . 700 ~ ~ ~OO ~ 1300 ,900' . 1900 í íOO'" . '300 , 20 ¡OO @ % @ . 2700 . 1700 . 700. 900 . 900 .900 9300 e. 50000 B- . 700 . 700 . ~.Œ?~ob 700 8300 . 700 1100 . 900 8300 . '100 8300 70d" . 500 8300 . 700 8300.900 . 700 8300 . 1 iDO . 7cßi 300 8300 .. 70C 2300. 700 9300 S:KWPO . 900 . 500 9300 . 900 " 1500 900" . 1700 " í 300 . 900 1100 80 60 £i.lUJ« ~...."ei~ t~¡'ri:o~ ~--::':i..._::": [r¡,c Vcrt;cc: DC¡J~'1S crc rc~crcr"Cc R¡{3(Joyon;g). Coorc:na:cs CfC i,., 'eet "c'CrCr1CC sio:: #45. P-ot ~ctcrc""cc ;s C;)2-45 VcrsÎor:#7. C'ealeo by b"';c"ae' For: V Johnson Jo:c D10:tcd : ?::?-Od-200~ @ C :::x:J ---- ~ --- <= ~ r-- @ @"OD 0> · 900 . 1300 rfj . JOO 0> · 100 & & 40 ~ .-, [ 900 i j ~:r- 1000 ~r ï 1100 ~ I r 1200 i r : r 1300 ! I v 800 ,,--..... - CD CD -+ ........." ; ; r ~ 400 ~ L 500 I ~ I]J:jL 600 ! L i ~ 700 U) o C -+ ::r ~ 300 100 200 2500 r 2400 " 0:J~ " " '" 4900 " . I.3700 . ..3500 . 3300 I3100 2300 2200 2100 "'" " " " " 2700' "-.,. 4700 " " " '-I ~500 " . *- 3300 2000 . ",3100 " 2900 1900 1800 '700 ~ % " " 2500~300 " . .... 2900 . 2700 1600 " 2900 ~ 4¡CO " " " 2500 ~500 \, 3300 ~ ~ " 2500 . 2700 '" 3900 . 230Ò, , , . ... 2700 . .... 2500 . 2300 1400 í300 1200 East (feet) -> Location : North Slope, Well: 45 A' 1: laSl~a, Structure : CO#2 Field : Alpine Field Pl~illiDS ...L 2900 3100 .. 2300 . 2500 " , --"',3700 " ..... 3500 " " 21 00 " " . .. 2300 ~ . 2300 ___ 2700 .... 2500 > 2100 . 2300 % .' :llitru) . 3íOO . 2,00 . 1900 .... 2300 \. ~ '1C9{¡0 ;;Jffi]JO . .. 21 00 . ;:> í 00 . í 900 ' "- 3300 . .. '900 YOO' .' 700 '900 " 2100 .. 7100 1í 00 1000 700 800 900 Qù 6900 í900 % \§ . 7' 00 \3 . 7900 % ~ ~ . . .' 2900 ~~ 1 ~- SOD . ~ ... , /09 ' 700 '- .:.. ~, ~J . í 700 flD _ ':"___J__,-- __J.__:..-___.::__L 600 500 Coor(J·"'(J~CS ere :~ ~cc: re'c...e.-ce s~o~ #1.5_ . rue Vcr::cc.:: 0cptr.s a'c re'crance !1.f(5(8:cyo!": 9). ð!".igi-¡< . ¡.p.u;¡:,~ :NTÞ:{) Crecteo ay a""cece For: V Johnson Jc:c p.c~tcc 7.:ì-Oct-200: i)'o: Rec'c~cc is CD2 -£5 Vcrs·o'1#7. 0ì LiJ5.' 1.00 JOG C ::0 --- ~ ---- <:= :t::::. r--- C :::J:J ---.. ~ ---- ~ r--- Crected by D"';C"Oe For: V Johnson lJo~c p:o::ed : 22-Cc~-200~ Dlo~ Rcfcrc""!cc ·s CQ2 -~5 Vcrs:o'1#7. Caoro'~!G:e'5 a~e ;'1 'CC~ (c~c"crcc s:o~ #"'5_ Tr...f: Vcrt:car ]cot"s arc rcfcrcrcc Rr<ß(Doyo~' 9). r'~-}~.i ~ ',600 /000 ;ì1,00 IN I'r:(~ :1800 3200 '--¡-~-~~ ' (JJ) . '. S' 00 3500 co. 3900 39.00 Qn -. ~ 3500 <f!J- . ..3900 ~ ." 1·/00 S", ?l00___ '{. . 3' 00'-- . ,..5 ~ 00 '-0 3iOO ~j50Õ '- ~ <Ð . 3',00 3500 \ 1,700 <Ð . 5500 .. 5' 00 . 3500 " ~)500 . 3900 " 5900 . 3900 .... 6,3Jì.O (cÂ V . 1,300 ..... 77~"% . 1.300 % , 1.100 . 5~00 %% , 1·300 LlOÒ- 590Ô"- " 3500 630Ò" , , 3900 670Ò.... . 1.300 '. 6700 .-- ~~ . 1,700 ". . 5 ~ 00.. PI'lilli DS Alasl-<:a, 3600 ~ooo . 1.300 c Á 700 \, 3500 ~O ill ... 2700 cm~ . 390~ 3100 ~7i'00 '-- " ',", 35QOßOO . 1.300 ~\3_900 . , L 700" 43'Q~ . 1.700 . 5100 c 550Q. <Ð% Structure: CD#2 Field : Alpine Field 1n0 JL-,,-À. L . Well: 45 Location North Slope, East (feet) -> ~~oo 1.800 5200 5600 % ..5iOO * 5500 * 5900 I . 9 ~ '" 7100 c Á 700 c 5100 .~ 4700',_ * 5WÒ', ',5100 '> 5500 . 550,~", : ':;;900 -~ 5900 . 5500 ... 6300 \ 6700 . 5900 \'. 7100 ~~~ 6000 % . 6300 * '5500 " 'em 6~00 7200 6800 ~ c 6700 * 7100 * 5900 " 6300 . 6300 ~ !45J 7600 8000 . ., 6700 8~00 8800 9200 9600 10000 10400 "00 @] . 7i 00 ~ 800 -- --,3100 , *" ~! 00 "\ 27G~,5500 .. 5900 '. ,6300 . 6700 - 1200 I i- i 600 .- 2000 í L - 2400 U) 0 C -f- 2800 ::r ,,--.., -+, CD - 3200 CD -f- '-/ I - 3600 V - "000 ~ - "-400 - 4800 - 5200 - 5600 ) Structure: CDI12 Field : Alpine Field Well: 45 CnJolcd by bmir:hcHJI For: V ,Johnson Dole ploH(d : /.íl.-Oc\··2001 Pial Reference i~ Cln.-4t> Vcrsiorlll7. Coordinatos ora in foot roferonco slot 11<15, JIPJhilli]ps AlasJlka, II1C. Vcrlical DcpLh! arc refcrence Location : North Slope, Alaska G:,¿òû ~1J1:l I~ ~ TRUE NORTH ~ [:=:J ~ 350 0 10 j~ü. .. 700 20 330 """ 30 (@,..... 320 40 GlJ..1,1',O·Ö'... "" 310" "" 50 300 60 290@J 70 280 80 770 0 90 260 100 250 1 10 740 120 &) ~3 0 L30 270 1 ~O 210 1 50 200 í 60 '190 'i 80 1 70 Nori:lc: ::):cne ":- (' 0 V e ; i ; n Cj Cylinder eel ^ ceD'c'lS s~ow ", err:") Vlecs:"Jed deo~(;s or' :<C~ e'c",cc We!1 .), \...... 0: 'G,AA~ ') Phillips Alaska, Inc. CD#2 45 slot #45 Alpine Field North Slope, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref Our ref License CD2-45 Version#7 prop44l8 Date printed Date created Last revised 22-0ct-200l 17-Jan-2001 22-0ct-2001 Field is centred on n70 20 37.100, w150 51 37.53 Structure is centred on n70 20 37.100, w151 1 42.976 Slot location is n70 20 17.304,w151 2 27.005 Slot Grid coordinates are N 5974344.093, E 371728.056 Slot local coordinates are 2012.68 S 1507.47 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ') J = GAA- ) Phillips Alaska, Inc. PROPOSAL LISTING Page 1 CD#2,45 Your ref : CD2-45 Version#? Alpine Field, North Slope, Alaska Last revised : 22-0ct-2001 Measured Inclin Azimuth True Vert R E C TAN G U L A R G RID C OORDS GEOGRAP H I C Depth Degrees Degrees Depth C 0 o R D I N A T E S Easting Northing COORDIN A T E S 0.00 0.00 0.00 0.00 O.OOS O.OOE 371728.06 5974344.09 n70 20 17.30 w151 27.01 100.00 0.00 102.50 100.00 O.OOS O.OOE 371728.06 5974344.09 n70 20 17.30 w151 27.01 200.00 0.00 102.50 200.00 O.OOS O.OOE 371728.06 5974344.09 n70 20 17.30 w151 27.01 250.00 0.00 102.50 250.00 O.OOS O.OOE 371728.06 5974344.09 n70 20 17.30 w151 27.01 350.00 2.00 102.50 349.98 0.38S 1.70E 371729.75 5974343.69 n70 20 17.30 w151 26.96 400.00 3.00 102.50 399.93 0.85S 3.83E 371731.87 5974343.18 n70 20 17.30 w151 26.89 500.00 4.82 ll5.01 499.70 3.19S 10.20E 371738.20 5974340.73 n70 20 17.27 w151 26.71 600.00 6.74 120.55 599.18 7.95S 19.06E 371746.98 5974335.82 n70 20 17.23 w151 26.45 700.00 8.70 123.63 698.27 15.13S 30.42E 371758.21 5974328.45 n70 20 17.16 w151 26.12 765.90 10.00 125.00 763.30 21.17S 39 . 2 5E 371766.94 5974322.26 n70 20 17.10 w151 25.86 800.00 11.00 123.94 796.82 24.69S 44.38E 371772.01 5974318.66 n70 20 17.06 w151 25.71 900.00 13.97 121.71 894 .45 36.36S 62.57E 371789.99 5974306.68 n70 20 16.95 w151 25.18 1000.00 16.94 120.25 990.82 50.05S 85.42E 371812.61 5974292.61 n70 20 16.81 w151 24.51 1078.05 19.27 ll9.41 1065.00 62.10S 106.47E 371833.45 5974280.21 n70 20 16.69 w151 23.90 1100.00 19.92 ll9.21 1085.68 65.70S ll2.89E 371839.81 5974276.49 n70 20 16.66 w151 23.71 1200.00 22.91 ll8.44 1178.77 83.29S 144.88E 371871.50 5974258.37 n70 20 16.49 w151 22.77 1269.92 25.00 ll8.00 1242.66 96.71S 169.90E 371896.28 5974244.53 n70 20 16.35 w151 22.04 1300.00 25.88 II 7.53 1269.82 102.73S 181.33E 371907.61 5974238.32 n70 20 16.29 w151 21. 71 1400.00 28.81 116.17 1358.64 123.458 222.32E 371948.24 5974216.91 n70 20 16.09 w151 20.51 1500.00 31.76 ll5.05 1444.98 145.238 267.80E 371993.34 5974194.37 n70 20 15.88 w151 19.18 1600.00 34.71 ll4.09 1528.61 168.00S 317.65E 372042.79 5974170.76 n70 20 15.65 w151 17.73 1628.60 35.56 ll3.85 1552.00 174.698 332.69E 372057.72 5974163.82 n70 20 15.59 w151 17.29 1700.00 37.67 ll3.27 1609.31 191.708 371.73E 372096.46 5974146.15 n70 20 15.42 w151 16.15 1800.00 40.64 ll2.55 1686.84 216.27S 429.89E 372154.19 5974120.60 n70 20 15.18 w151 14.45 1900.00 43.61 ll1. 92 1761.00 241.648 491. 97E 372215.83 5974094.19 n70 20 14.93 w151 12.63 1940.15 44.80 ll1.68 1789.78 252.04S 517.97E 372241.65 5974083.36 n70 20 14.83 w151 11.88 2000.00 44.80 ll1.68 1832.25 267.628 557.15E 372280.56 5974067.12 n70 20 14.67 w151 10.73 2500.00 44.80 lll.68 2187.01 397.788 884.57E 372605.70 5973931. 45 n70 20 13.39 w151 01.17 2552.13 44.80 111.68 2224.00 411.358 918.70E 372639.60 5973917.31 n70 20 13.26 w151 00.17 2795.95 44.80 ll1.68 2397.00 474.828 1078.36E 372798.15 5973851.15 n70 20 12.64 w151 55.51 2800.18 44.80 ll1. 68 2400.00 475.92S 1081.13E 372800.90 5973850.00 n70 20 12.62 w151 55.43 3000.00 44.80 111.68 2541. 78 527.948 12ll.98E 372930.84 5973795.78 n70 20 12.ll w151 51.61 3268.09 44.80 lll.68 2732.00 597.738 1387.53E 373105.17 5973723.04 n70 20 11.43 w151 46.48 3500.00 44.80 111.68 2896.55 658.108 1539.39E 373255.98 5973660.ll n70 20 10.83 w151 42.04 4000.00 44.80 lll.68 3251. 31 788.27S 1866.80E 373581.11 5973524.45 n70 20 09.55 w151 32.48 4500.00 44.80 lll.68 3606.08 918.438 2194.21E 373906.25 5973388.78 n70 20 08.27 w151 22.92 4831. 09 44.80 lll.68 3841.00 1004.628 24ll.02E 374121. 55 5973298.94 n70 20 07.42 w151 16.59 5000.00 44.80 ll1. 68 3960.84 1048.598 2521.63E 374231. 39 5973253.11 n70 20 06.99 w151 13.36 5135.52 44.80 111.68 4057.00 1083.878 2610.37E 374319.52 5973216.34 n70 20 06.64 w151 10.77 5500.00 44.80 111.68 4315.61 1178.758 2849.04E 374556.53 5973117.44 n70 20 05.71 w151 03.80 6000.00 44.80 111. 68 4670.38 1308.928 3176.45E 374881.67 5972981.77 n70 20 04.43 w151 54.24 6500.00 44.80 111.68 5025.14 1439.08S 3503.86E 375206.80 5972846.11 n70 20 03.15 w151 44.68 7000.00 44.80 ll1. 68 5379.91 1569.24S 3831. 27E 375531.94 5972710.44 n70 20 01.87 w151 35.12 7397.57 44.80 III . 68 5662.00 1672.748 4091.61E 375790.47 5972602.56 n70 20 00.85 w151 27.52 7500.00 44.80 111.68 5734.68 1699.418 4158.69E 375857.08 5972574.77 n70 20 00.59 w151 25.56 8000.00 44.80 111. 68 6089.44 1829.57S 4486.10E 376182.22 5972439.10 n70 19 59.31 w151 0 16.00 8028.97 44.80 111.68 6110.00 1837.118 4505.07E 376201.06 5972431.24 n70 19 59.23 w151 0 15.45 8500.00 44.80 111. 68 6444.21 1959.738 4813.51E 376507.36 5972303.43 n70 19 58.02 w151 0 06.44 89ll.25 44.80 111.68 6736.00 2066.79S 5082.80E 376774.78 5972191. 85 n70 19 56.97 w150 59 58.58 8990.10 44.80 111. 68 6791.95 2087.32S 5134.44E 376826.06 5972170.45 n70 19 56.77 w150 59 57.07 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot ~45 and TVD from RKB(Doyon19) (52.00 Ft above mean sea level). Bottom hole distance is 8866.01 on azimuth 126.70 degrees from wellhead. Total Dogleg for wellpath is 103.67 degrees. Vertical section is from wellhead on azimuth 114.99 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ C ~r.1"'^" tn·f I ~.1 Hi ¡ /V,._ ') ) Phillips Alaska, Inc. PROPOSAL LISTING Page 2 CD#2,45 Your ref : CD2-45 Version#7 Alpine Field, North Slope, Alaska Last revised : 22-0ct-2001 Measured Inclin Azimuth True Vert R E CTANGULAR G RID C OORDS G E 0 GRAPHIC Depth Degrees Degrees Depth C 0 ORDINATES Easting Northing COO R D I NATES 9000.00 45.17 112.34 6798.95 2089.94S 5140.93E 376832.50 5972167.72 n70 19 56.74 w150 59 56.88 9100.00 49.08 118.55 6867.01 2121.50S 5206.98E 376898.00 5972135.04 n70 19 56.43 w150 59 54.95 9187.19 52.74 123.38 6922.00 2156.36S 5264.93E 376955.35 5972099.21 n70 19 56.09 w150 59 53.26 9200.00 53.29 124.05 6929.70 2162.04S 5273.44E 376963.76 5972093.39 n70 19 56.03 w150 59 53.01 9300.00 57.73 128.95 6986.34 2211 .11S 5339.59E 377029.07 5972043.22 n70 19 55.55 w150 59 51.08 9353.62 60.18 131. 39 7014.00 2240.74S 5374.68E 377063.65 5972013.00 n70 19 55.26 w150 59 50.06 9400.00 62.33 133.40 7036.30 2268.16S 5404.70E 377093.20 5971985.08 n70 19 54.99 w150 59 49.18 9500.00 67.07 137.47 7079.04 2332.58S 5468.06E 377155.46 5971919.61 n70 19 54.35 w150 59 47.33 9559.93 69.95 139.78 7101.00 2374.42S 5504.90E 377191.58 5971877.15 n70 19 53.94 w150 59 46.26 9600.00 71.90 141.27 7114.09 2403.65S 5528.97E 377215.15 5971847.52 n70 19 53.66 w150 59 45.56 9626.35 73.18 142.24 7122.00 2423.39S 5544.53E 377230.38 5971827.52 n70 19 53.46 w150 59 45.10 9700.00 76.80 144.87 7141.07 2480.61S 5586.77E 377271.64 5971769.60 n70 19 52.90 w150 59 43.87 9717.79 77.68 145.49 7145.00 2494.86S 5596.68E 377281.31 5971755.19 n70 19 52.76 w150 59 43.58 9800.00 81.75 148.32 7159.68 2562.60S 5640.83E 377324.30 5971686.71 n70 19 52.09 w150 59 42.29 9900.00 86.73 151.68 7169.71 2648.73S 5690.55E 377372.55 5971599.76 n70 19 51.24 w150 59 40.84 9905.34 87.00 151. 86 7170.00 2653.43S 5693.07E 377374.99 5971595.02 n70 19 51.20 w150 59 40.77 9905.36 87.00 151.86 7170.00 2653.45S 5693.08E 377375.00 5971595.00 n70 19 51.20 w150 59 40.77 10005.36 88.00 151.86 7174.36 2741.55S 5740.20E 377420.62 5971506.13 n70 19 50.33 w150 59 39.39 10105.36 89.00 151.86 7176.98 2829.69S 5787.34E 377466.26 5971417 .20 n70 19 49.46 w150 59 38.02 10205.36 90.00 151.86 7177.85 2917.87S 5834.50E 377511.92 5971328.25 n70 19 48.60 w150 59 36.64 10226.35 90.21 151.86 7177.81 2936.37S 5844.40E 377521.50 5971309.58 n70 19 48.41 w150 59 36.36 10500.00 90.21 151.86 7176.81 3177.68S 5973.46E 377646.46 5971066.15 n70 19 46.04 w150 59 32.59 11000.00 90.21 151.86 7174.98 3618.57S 6209.27E 377874.77 5970621.37 n70 19 41.70 w150 59 25.72 11500.00 90.21 151.86 7173.15 4059.47S 6445.09E 378103.07 5970176.59 n70 19 37.36 w150 59 18.84 12000.00 90.21 151.86 7171.32 4500.36S 6680.90E 378331.38 5969731.80 n70 19 33.03 w150 59 11.96 12500.00 90.21 151.86 7169.49 4941.26S 6916.71E 378559.69 5969287.02 n70 19 28.69 w150 59 05.09 12905.82 90.21 151.86 7168.00 5299.11S 7108.11E 378744.99 5968926.02 n70 19 25.17 w150 58 59.51 12905.84 90.21 151.86 7168.00 5299.12S 7108.12E 378745.00 5968926.00 n70 19 25.17 w150 58 59.51 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #45 and TVD from RKB(Doyon19) (52.00 Ft above mean sea level). Bottom hole distance is 8866.01 on azimuth 126.70 degrees from wellhead. Total Dogleg for wellpath is 103.67 degrees. Vertical section is from wellhead on azimuth 114.99 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 0: 'G ':) - ) ') Phillips Alaska, Inc. CD#2,45 Alpine Field, North 51ope, Alaska PROP05AL LI5TING Page 3 Your ref CD2-45 Version#7 Last revised : 22-0ct-2001 Comments in wellpath ===================== MD Rectangular Coords. Comment TVD ----------------------------------------------------------------------------------------------------------- 250.00 250.00 0.005 O.OOE KOP 400.00 399.93 0.855 3.83E Begin Bid/Turn Rt 765.90 763.30 21.175 39.25E Beg 3/100 Bld/Trn Lft 1078.05 1065.00 62.105 106.47E West 5ak 1628.60 1552.00 174.695 332.69E Base Permafrost 1940.15 1789.78 252.045 517.97E EOC 2552.13 2224.00 411.355 918.70E C-40 2795.95 2397.00 474.825 1078.36E C-30 2800.18 2400.00 475.925 1081.13E 9 5/8" Casing pt 3268.09 2732.00 597.735 1387.53E C-20 4831.09 3841.00 1004.625 2411.02E K-3 5135.52 4057.00 1083.875 2610.37E K-2 7397.57 5662.00 1672.745 4091.61E Albian-97 8028.97 6110.00 1837.115 4505.07E Albian- 96 8911 .25 6736.00 2066.795 5082.80E HRZ 8990.10 6791. 95 2087.325 5l34.44E Begin Fnl Bld/Trn 9187.19 6922.00 2156.365 5264.93E K-l 9353.62 7014.00 2240.745 5374.6eE LCU 9559.93 7101.00 2374.425 5504.90E Miluveach A 9626.35 7122.00 2423.395 5544.53E Alpine D 9717.79 7145.00 2494.865 5596.68E Alpine C 9905.34 7170.00 2653.435 5693.07E Target - Csg pt 9905.36 7170.00 2653.455 5693.08E CD2-45 Heel Rvsd 25-5ep-Ol 10226.35 7177.81 2936.375 5844.40E EOC 12905.82 7168.00 5299.115 7108.11E TD - Csg pt 12905.84 7168.00 5299.125 7108.12E CD2-45 Toe Rvsd 25-5ept-Ol Casing positions in string 'A' ------ ------- ----------------- -- - --- -- - ---- - - - --- - ---------- Top MO Top TVO Rectangular Coords. Bot MO Bot TVO Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 O.OOE 2800.18 2400.00 O.OOE 9905.36 7170.00 475.925 2653.455 1081.13E 9 5/8" Casing 5693.08E 7" Casing 0.00 0.00 0.005 0.005 Targets associated with this wellpath ======== =:;:::===:;: ======= ===============::: Target name Geographic Location T.V.O. Rectangular Coordinates Revised - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - -- - - - - - - - - - - - - - - - - - - - - -- C02-45 Heel Rvsd 25- 377375.000,5971595.000,-2.000 7170.00 C02-45 Toe Rvsd 25-5 378745.000,5968926.000,0.0000 7168.00 2653.455 5299.125 5693.08E 15-0ct-1997 7108.12E 15-0ct-1997 0:' G vt ... ) ') Phillips Alaska, Inc. Post Office Box 1 00360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 October 28,2001 Alaska Oil and Gas Conservation Commission 333 West ¡th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD2-45 Dear Sir or Madam: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the Alpine CD2 drilling pad. The intended spud date for this well is November 14, 2001. It is intended that Doyon Rig 19 be used to drill the well. The well CD2-45 will be drilled to penetrate the Alpine sand horizontally. 7" casing will then be run and cemented in place. A horizontal section will then be drilled and the well completed as an open hole producer. At the end of the work program the well will be shut in awaiting surface connection. This well is part of a two well evaluation of the effects of oil based mud on the producing interval. Mineral oil is the base fluid for the oil mud. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 1 0-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program, including a request for approval of annular pumping operations. 4. A drilling fluids program summary. 5. Proposed completion diagram. 6. Proposed completion diagram with open hole isolation options. 7. Pressure information as required by 20 ACC 25.035 (d)(2). 8. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to this application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold layout as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. RECEIVED OCT 3 0 Z001 Alaska Oil & Gas Cons. Commission Anchorage ) ) If you have any questions or require further information, please contact Vern Johnson at 265-6081 or Chip Alvord at 265-6120. ~Since Iy, -¿ <- . --- Vern Johnson Drilling Engineer Attachments cc: CD2-45 Well File / Sharon Allsup Drake Chip Alvord Cliff Crabtree Meg Kremer Nancy Lambert Lanston Chin e-mail: ATO 1530 A TO 868 ATO 848 ATO 844 Anadarko - Houston Kuukpik Corporation Tommy_Thompson @anadarko.com RECEIVED OCT 3 0 2001 Alaska Oil & Gas Cons. Commission Anchorage ') ') American Express~ Cash Advance Draft 173 DATE 30 O~þ4ý' h:J¡AO/IO?I ~~~;~ :;E $!J ..f ¡I/r¡þ !lfrXlC!:-¡ I $1/00. 00 ______ tJltL ~ oÚ~ A-~ /Ibø. · DOLLARS Issued by Integrated Payment System, Inc. Englewood,Colorado Xi" IDFORA~OUNTOV. $1000 ~ Payable at NolWest Bank of Grand Junction - Downtown, NA SHARON P- D>tè, Grand Junction. Colorado ,.. ~ 7- PERIOD ENDING c,J) d.-'-lÇ" I: ~ 0 2 ~ 0 0 ... 0 0 I: ~ ~ 5 III 0 ~ ? 5 000 5 :. b III 0 ~ 7 :. " .... .... ...... ,." ' ,_. ,...,-' - ... ~) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Abandon _ Suspend _ Alter casing _ Repair well _ Change approved program _ 1. Type of request: 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 9951 0..Q360 4. Location of well at surface 1706' FNL"1547' FEL, Sec. 2, T11N, R4E, UM At top of productive interval 789' FNL¡ 1260' FEL, Sec. 2, T11 N, R4E, UM At effective depth . At total depth 1856' FSL, 2577' FWL, Sec. 35, T12N, R4E, UM , 12. Present well condition summary Total depth: measured true vertical 11056 7131 11056 -7131 Effective dep~: measured true vertical Length 77' 2417' 16" 9-5/8" Casing Conductor Surface Size Production 7634' 7" Perforation depth: measured None true vertical None Operational shutdown _ Plugging _ Pull tubing _ 5., Type of Well: Development _X Exploratory _ Stratigraphic _ Service _ ---' Per APD --- Per APD feet Plugs (measured) feet feet Junk (measured) feet Cemented; , 261 Sx AS~ : 376 Sx AS;III L & 240 Sx 15.8 cla~'G 138 Sx 15.8 class G Packers & SSSV (type & measured depth) Tubing (size, grade, and measured depth 4.5" 12.6#, L-80 @ 7412' MO Re-enter suspended well _ Time extension _ 'Stimulate _ Variance Perlorate 6. Datum elevation (DF or KB feet) RKB 52 feet 7. Unit or Property name Other _x Annular Disposal Colville River Unit 6. Well number CD2·14 9. Permit number I approval number 201-177 10. API number 50-103-.20390-00' 11. Field I Pool Colville River Field I Alpine Oil Pool Measured Depth 114' 2454' True vertical Depth 114' .2343' 7671' 72031 RECEIVED OCT 0 9 2001 Alaska Oil & Gas Cons. Commission Anchorage 7" Baker S3 Permanent Packer@ 7297' MD, Camco Bal-O @ 2101' MD 13. Attachments D'esaiption summary of proposal_ Detailed operations program _ , BOP sketch _ Refer to attached momlng drilling report for LOT test, surface cement details and casing detail sheets. schematic _X 14. Estimated date for commencing operation 15. Status of well classification as: October 22,2001 16. If proposal was verbally approved Oil_X Gas Suspended_ Name of approver Date approved Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed . 11 I / í\, ¡ ChlpAlvord ~L. (¡Æ"L. Title: Alpine Drilling Team Leader Questions? Call Vem Johnson 265-6081 Dat~ /01 OJ( 9' FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity _ BOP Test _ location clearance _ Mechanical I Test ent fonn required 10- {Q ~ ,-\-oC. Approved by order of the Commi j Form 1 D-403 Rev 06115/86 . nl JPJ JrATF Commissioner . I Approval 00. ~l- ~ ~ 0"1\.0 k::..r <Jr> pc:. G ( Date /J / c¡ I () I SUBMIT IN TRIPLICATE ) ) Casing Detail ~...fJ.lfJu $J!rlaç,f#..""Q,ªsifJY ;P~lU,PS, PHILLIPS Alaska, Inc. m A Subsidiary of PHilLIPS PETROLEUM COMPANY Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Jts 3 to 57 55 Jts Doyon 19 RKB to LDS FMC Gen V Hanger 9-5/8" 36# J-55 BTC Csg Davis Lynch Float Collar 9-5/8" 36# J-55 BTC Csg Davis Lynch Float Shoe Jts 1 to 2 2 Jts 9- 5/8" shoe @ TD 12 1/4" Surface Hole RUN TOTAL 32 BOWSPRING CENTRALIZERS· 1 per jt on Jt #1 - #12 (On stop rings of Jt #1 & #3) #14,16,18,20,22,24,26,28,30,32,34,36,38, 40,42,44,46,48,50,52,54 Last 8 joints stay out # 58 thru # 65. Use Best-O-Life 2000 pipe dope Remarks: Up Wt -160 k Dn Wt -140 k Block Wt - 70 Well: Date: LENGTH 36.80 2.95 2333.62 1.53 77.50 1.71 2464.00 Supervisor: Don Mickey CD2~14 9/21/01 DEPTH TOPS 36.80 39.75 2373.37 2374.90 2452.40 2454.11 ~ IfI7I ~ ) PHILLIPS ALASKA INC. Cementing<Report Legal Well Name: CD2-14 Common Well Name: CD2-14 Event Name: ROT - DRILLING Primary Hole Size: 12.250 (in) TMD Set: 2,454 (ft) Date Set: 9/22/2001 Csg Type: Surface Casing Csg Size: 9.625 (in.) Cmtd. Csg: Surface Casing Cement Co: Dowell Schlumberger Rot Time Start: : Rec Time Start:08:30 Report #: Start: 1 9/18/2001 ) Page 1 of 2 Spud Date: 9/20/2001 Report Date: 9/23/2001 End: Cement Job Type: Squeeze Open Hole Hole Size: SO TMD: (ft) SO Date: SO Type: Cmtd. Csg: Cementer: . Squeeze Casing Hole Size: TMD Set: Date Set: Csg Type: SO TMD: SO Date: Cmtd. Csg: Plug Hole Size: Top Set: (ft) BTM set: (ft) Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Pipe Movement Pipe Movement: Reciprocating Time End: : Time End: 11 :00 RPM: SPM: Init Torque: (ft-Ibf) Stroke Length: 25.0 (ft) Avg Torque: (ft-Ibf) Max Torque: (ft-Ibf) Drag Up: 165,000 (Ibs) Drag Down: 125,000 (Ibs) Type: Cement Casing Volume Excess %: 300.00 Meas. From: Time Circ Prior To Cementing: 2.00 Mud Circ Rate: 294 (gpm) Mud Circ Press: 500 (psi) Start Mix Cmt: 11 :20 Start Slurry Displ: 12:30 Start Displ: 12:30 End Pumping: 13:00 End Pump Date: 9/22/2001 Top Plug: Y Bottom Plug: Y Stage No: 10ft Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 7.00 (bbllmin) 7.00 (bbl/min) Y 760 (psi) 1 ,100 (psi) 5 (min) Y Returns: full returns Total Mud Lost: (bbl) Cmt Vol to Surf: 125.00 (bbl) Ann Flow After: N Mixing Method: Density Meas By: Type: Spud Mud Density: 9.6 (ppg) Visc: 50 (s/qt) Bottom Hole Circulating Temperature:68 ("F) Displacement Fluid Type:Mud PVIYP: 20 (cp)/17 (lb/100ft2) Gels 10 sec: 7 (lb/100ft2) Gels 10 min: 27 (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: 9.6 (ppg) Volume: 165.90 (bbl) Slurry Data Fluid Type: PRIMARY Slurry Interval: 1,812.00 (ft}To: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Mud Data· Stage No: t SlurryNo:10f2 Description: ASLite Cmt Vol: 297.0 (bbl) Slurry Vol:376 (sk) Temperature: (OF) Temperature: (OF) Temperature: (OF) Class: Density: 10.70 (ppg) Yield: 4.44 (ft3/sk) Water Vol: (bbl) Other Vol: 0 Purpose: FILLER CEM Mix Water: (bbl) Foam Job: N Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) Printed: 9/25/2001 3:37:10 PM '\ ) ) ~ ~ ~ PHILLIPS ALASKA INC. Cementing.R~port Legal Well Name: CD2-14 Common Well Name: CD2-14 Event Name: ROT - DRILLING Report #: Start: 1 9/18/2001 stage No: 1 Slurry No: 26f 2 Slurry Data Fluid Type: TAIL Description: Slurry Interval: 2,454.00 (ft)To: 1,954.00 (ft) Cmt Vol: 49.0 (bbl) Water Source: Slurry Vol240 (sk) Class: G Density: 15.80 (ppg) Yield: 1.15 (ft3/sk) Water Vol: (bbl) Other Vol: 0 Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Time Compressive Strength 1: Compressive Strength 2: Temperature: (OF) Temperature: (OF) Temperature: (OF) Casing Test Shoe Test Test Press: 2,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: N Pressure: 16.10 (ppge) Tool: N Open Hole: 30 (ft) Hrs Before Test: Liner Lap: Pas Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Log/Survey Evaluation Interpretation Summary CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: N Bond Quality: Temp Survey: N Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: N Number of Remedial Squeezes: Page 2 of 2 Spud Date: 9/20/2001 Report Date: 9/23/2001 End: Purpose: SHOE INTEG Mix Water: (bbl) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Liner Top Test Tool: N Tool: N Printed: 9/25/2001 3:37:10 PM CD2-14 ) ) .~ Phillips Alaska, Inc. Daily Drilling Report AFE 24 H rs TMD TVD DFS REPT NO. DATE Prog 998D09 0' 2,465' 2,353' 2.13 3 9/22/01 ~.. Well CD2-14 Sidetrack Supervisor Don Mickey Proposed TMD 10,699' Daily Cost $172,029 Cumulative Cost $629,137 Last Safety Meeting Incident 1st 24 hrs? Pressure Test(s) Type I Date I TM D I TVD I MW I Press Tot. press I EMW 110'10'10 ppglO psilO.OO psilO.OO ppg Last BOP Test Rig Name Doyon 19 Field Name Alpine Current Status Ci~c - Prep to test casing Event Code ODR Finish BOP test - 24 HR Forecas f"l/U BHA - Test Csg - Drill 8 1/2" hole Next BOP Test Last Survey TMD: INC: Azim: Last Casing Next Casing 9/24/01 6,255 0.66 126.27 9.625 (in) @ 2454 7 (in) @ 7698 Operations Summary From To H ou rs Phase ActiVitYSUbCOdE~~:'S~ TroublE Operation 00:00 02:00 2 SURFAC DRILL PULD P Finish laying down BHA 02:00 03:00 1 SURFAC CASE RURD P Rig up to run 9 5/8" casing 03:00 08:00 5 SURFAC CASE RUNC P PJSM - Ran 57 jts. 9 5/8" 36# J-55 BTC wi shoe @ 2454' - float collar @ 2373' 08:00 08:30 0.5 SURFAC CASE RURD P RIg down tongs - fill up tool - M/U cmt head - blow down top drive 08:30 10:30 2 SURFAC CEMENT CIRC P Circulate & condition mud for cement job PJSM - Cement 9 5/8" csg : pumped 40 bbls viscosified water wi nut plug - drop btm plug - 50 bbls Arco spacer @ 10.5 ppg - mix & pump 10:30 12:30 2 SURFAC CEMENT PUMP P 297 bbls (376 sxs) 10.7 ppg AS 3 LIte - Observed nut plug marker @ shakers - switch to tail slurry 49 bbls (240 sxs) 15.8 ppg Class G - drop top plug wi 20 bbls fresh water Displace cement wi 9.6 ppg mud @ 7 bblsl min - 550 to 760 psi - slow pump to 3.5 bblsl min for 12:30 13:00 0.5 SURFAC CEMENT DISP P last 26 bbls of displacement - bumped plug wi 165.9 bbls - CIP @ 1300 - floats held - full returns wi 125 bbls 10.7 ppg cmt returns to surface 13:00 14:00 1 SURFAC CEM ENT PULD P Rig down cement head - LI D landing jt. - 14:00 15:00 1 SURFAC CEMENT OTHR Clean up after cmt job - flush 20" Hydril & flow line 15:00 16:30 1.5 SURFAC DRILL PULD P PJSM - NIU 20" Hydril & diverter system 16:30 18:30 2 INTRM 1 DRILL PULD P Install FMC Unihead & test to 1000 psi for 10 mins 18:30 21:00 2.5 INTRM 1 DRILL OTHR P N/U 13 5/8 5K BOPE - change top drive saver sub 21:00 00:00 3 INTRM 1 DRILL OTHR P PJSM - Rig up test equipment - test BOPE 24 Hr. LID BHA - Run & Cmt 9 5/8" casing - Test BOPE Sum: Date Source 9/22/01 CD2-14 compan~ TMUd Density ype M-I Spud Mud 9.6 Bit/Run 2/2 Size Manuf. HYCA 8.5 ~.. ) ) Injection Volume Destination Total for destination 29,613 1,827 Source Total: 2,962 CD2-24 FV 44 Mud Data PV /VP 10se~ / 10 min / WL/HTHF MBT 30 mm Gels 8/ 16 4/11/15 10.8/0 22.5 PH 8 Bits T Serial Jets or TFA Depth Date ype No. In In DS70FHPV 24312 jO.34375jO.34375jO.34375 2465' 9/23/01 Flowline Drilling Temp Solids o 2.4 I-O-D-L-B-G-O-R 0-0-- --- - ,~ CASING TEST and FORMATION INTEGRITY TEST Well Name: CD2-14 Date: 9/23101 Supervisor: D. Mickey Reason(s) for test: o Initial Casing Shoe Test o Formation Adequacy for Annular Injection o Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8", 36#, J-55, STC CSG Casing Setting Depth: 2,454' TMD Hole Depth: 2,485' TMD 2,331' TVD 2,373' TVD Mud Weight: 9.6 ppg Length of Open Hole Section: 31' EMW= Leak-off Press. + Mud Weight = 790 psi + 9.6 ppg 0.052 x TVD 0.052 x 2,331' EMW for open hole section = 16.1 ppg Used cement unit Rig pump used NO #2 Pump output = 0.0997 bps Fluid Pumped = 0.9 bbls Fluid Bled Back = 0.8 bbls 2,800 psi 2,700 psi 2,600 psi - 2,500 psi 2,400 psi 2,300 psi 2,200 psi 2,100 psi 2,000 psi 1,900 psi 1,800 psi W 1,700 psi 0:: 1,600 psi :J 1,500 psi ~ 1,400 psi W 1,300 psi 0:: 1,200 psi c.. 1,100 psi 1,000 psi 900 psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 1./ 200 psi _~ 100 psi Y o psi o 111111111 1111'1JJJj1-I~I.lL!.J ~L!J~L~t' II! I ~ III ""·l ~~ ITIMELlNE I 1~"·~I:[f.TI&f~ ----LEAK-OFF TEST ...... CASING TEST HU LOT SHUT IN TIME -:~ CASING TEST SHUT IN TIME -+-TIME LINE 10 20 30 STROKES 40 50 NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above Modified by Scott Reynolds LEAK-OFF DATA I ¡ MINUTES FOR LOT STROKES PRESSURE r~~~~=~~~~~~~~~¡~~~~~~~~~~~~~~~~~~~~~~~p~(.~~~~ : : 1.0 I 150 pSI : f~~~~~~~~~~~~~~~t~~~~~~~~~~~~~~t~~~~~~~~~1~~~i r~~~~=~~~~~~~~~¡~~~~~~~º~~~~~~~~~~~~~~e~~~~~~ I I 5.0 I 450 pSI I f~~~~~~~~~~~~~~~t~~~~~~~~~~~~~~t~~~~¡~~~1~~~i ¡~~~~~~~~~t~~~~~~~~~~~I~~~~~~f~~~~ I I I I r=:=:::::f::::=:::::~=:=:::=:::::~ r--------------T---------------r---------------, t--------------t--------------t---------------i 1:::==::::::::+:::=::::::::::1:=:::=::::::::1 r---------------T---------------r----------------l 1::::=:::::::::+:=::::::::::::f:::::::==:::::1 r---------------1 ! ! I ~ I I I SHUT IN TIME I SHUT IN PRESSURE ~I~:~ß::E::==::::::¡::1{f.~~:::¡ I 2.0 mm : I 750 pSI I [i~~~g~l~~~~~~~~~~]~~~~H~I~~] I 6.0 mm I I 720 pSI : 1~~~~~f~~I---~~~~~~~~i:--~!I~~~] 60 M ~~Jsk~~~H~L,~!~~~!,l~~ CASING TEST DATA MINUTES FOR CSGTEST STROKES PRESSURE [~~~=~~~~~~~~¡~~~º~~!E~~~~r~~~Q~~~C~~~1 ! : 2 stks : 130 psi ; F~~~~~~~~~~~~~F~~ì~~~~~~~~F~~~~~=~~F~t [~~~~~~~~~~~~~¡~~I!!E~~~~¡~~~~~~J?-~C~1 ¡ I 10 stks : 990 psi I !--------------rTfsikš--r-f~1-5(fpšTI r--------------rT4-stkš--r-f~3Õ(fpšTI r--------------rTErsikš--r-f~46Õ-pšTi }--------------+--------------+-------------.--t : : 18 stks : 1,650 pSI I !---------------r--2-õ-sikš--r1~ã4õ-pšTI r---------------r2-2-sikš--r2~õãõ-pšTI r-------------r-2-4-sikš--r2~44ÕpšTi [~~~~~~T~~~~~~~~~g~~~~~j t~~~~~~~~~~~~~~t~~~~~~=~~~~~t~~~~~~~~~~~~~~~l t---------------t--------------t----------------i I I I I : SHUT IN TIME ¡ SHUT IN PRESSURE ~--- ------------+- -------------------------------- ! 0.0 mìn I ¡ 2.520 psi ¡ F~~~~~~~~~F~~~~~~~~~~~~~F~~~~~~~~Ft r~~IQ~~~~~~r~~~~~~~~~~~~~r~~~~~~e~~~1 I 4.0 mfn : I 2,490 pSI ; F~~~~~~~~~~F~~~~~~~~~~~~~F~~~~~~~~Ft [~¡~~~~jg~~E~~~~~~~~~~~~~E~~~;~~~;Ef ! 9.0 mìn ! ! 2,480 psi ! r--1-Œ(fñi¡ñ-T--------------r2~4ãõ-pšTI Ef~5=~!H::::::=:::::H~~H~::1 : ¿5.0 mm : : 2,470 pSI I CIº~º~6]}~~I~~~~~~~~~~~~I~~~*?~~~~T] ~ -~ NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ) " Casing Detail Z:: !vff!rmediate Casing Phillips Alaska, Inc. Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Doyon 19 RKS to LOS FMC 11" X 7" Hanger Jts 3 to 186 184 Jts 7" 26# L-80 STCM Csg 7" Davis Lynch Float Collar Jts 1 to 2 2 Jts 7" 26# L-80 STCM Csg 7" Davis Lynch Float Shoe 8-1/2" TO 1 straigtlt blade centralízer per jt # 2 & #4 - # 19, # 126, 127, 128 then every other jt. F I #1 ~~O to # 182 47 total centralizers Use Best-a-Life 2000 pipe dope Remarks: On Wt = 175 Block Wt= 70K Up Wt =300 Well: Date: LENGTH 35.20 1.79 7547.27 1.43 83.24 1.75 Supervisor: Don Mickey CD2M14 9/26/01 DEPTH TOPS 35.20 36.99 7584.26 7585.69 7668.93 7670.68 7681.00 .~ ~ ) Legal Well Name: CD2-14 Common Well Name: CD2-14 Event Name: ROT - DRILLING Primary Hole Size: 8.500 (in) TMD Set: 7,671 (ft) Date Set: 9/29/2001 Csg Type: Intermediate Casing/Li Csg Size: 7.000 (in.) Cmtd. Csg: OPEN HOLE Cement Co: Dowell Schlumberger Rot Time Start: : Rec Time Start:OO:OO Time End: : Time End: 01 :30 Type: Cement Casing Volume Excess %: 40.00 Meas. From: Time Circ Prior To Cementing: 1.50 Mud Circ Rate: 294 (gpm) Mud Circ Press: 790 (psi) PHILLIPS ALASKA INC. . Cementing Report Report #: Start: 2 9/18/2001 Cement·Job Type: Primary Squeeze Open Hole Hole Size: SQ TMD: (ft) SQ Date: SQ Type: Cmtd. Csg: RPM: SPM: Squeeze Casing Hole Size: TMD Set: Date Set: Csg Type: SQ TMD: SQ Date: Cmtd. Csg: Cementer: Jerry Culpepper ) Page 1 of 2 Spud Date: 9/20/2001 Report Date: 9/29/2001 End: Plug Hole Size: Top Set: (ft) BTM set: (ft) Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Pipe ·Movemelit Pipe Movement: Reciprocating Init Torque: (ft-Ibf) Stroke Length: 25.0 (ft) Avg Torque: (ft-Ibf) Drag Up: (Ibs) Stage No: 1 of1 Start Mix Cmt: 00:45 Start Slurry Displ: 00:55 Start Displ: 01 :00 End Pumping: 01 :45 End Pump Date: 9/29/2001 Top Plug: Y Bottom Plug: Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 7.00 (bbl/min) 7.00 (bbl/min) Y 800 (psi) 1 100 (psi) 5 (min) Y Type: Non-Disp. LS Density: 9.7 (ppg) Visc: 41 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type:Mud Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: To: (ft) T est Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Mud Data Max Torque: (ft-Ibf) Drag Down: (Ibs) Returns: full circ Total Mud Lost: (bbl) Cmt Vol to Surf: (bbl) Ann Flow After: N Mixing Method: Density Meas By: PVIYP: 8 (cp)/22 (lb/100ft2) Gels 10 sec: 8 (lb/100ft2) Gels 10 min: 10 (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: 9.0 (ppg) Volume: 290.00 (bbl) Stage No: 1 Slurry No:10f3 Description: ARCO wash Cmt Vol: 20.0 (bbl) Density: 8.30 (ppg) Slurry Vol: (sk) Water Vol: (bbl) Class: Yield: (ft3/sk) Other Vol: 0 Temperature: ("F) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Purpose: SPACER Mix Water: (bbl) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 10/1/2001 9:33:05 AM ) ) ..~ TfTiI ~¡ PHILLIPS ALASKA INC. Cementing Report Page 2 of 2 Legal Well Name: CD2-14 Common Well Name: CD2-14 Event Name: ROT - DRILLING Report #: Start: 2 9/18/2001 Spud Date: 9/20/2001 Report Date: 9/29/2001 End: Stage No: 1 SlurryNo:2<of3 51 urry Data Fluid Type: FLUSH Slurry Interval: (ft) To: (ft) Water Source: Description: ARCO Spacer Class: Cmt Vol: (bbl) Density: 12.50 (ppg) Yield: (fP/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Purpose: SPACER Mix Water: (bbl) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: ("F) Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) Stage No: fSlurry No: 3 of3 Slurry Data Fluid Type: PRIMARY Description: Slurry Interval: 7,671.00 (ft}To: 6,884.00 (ft) Cmt Vol: 31.0 (bbl) Water Source: Slurry Vol:138 (sk) Class: G Density: 15.80 (ppg) Yield: 1.15 (fP/sk) Water Vol: 16.0 (bbl) Other Vol: 0 Purpose: PRIMARY Mix Water: (bbl) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) ("F) Pressure (psi) (psi) Casing Test Shoe Test Liner Top Test Test Press: 3,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: Y Pressure: 12.50 (ppge) Tool: N Open Hole: 30 (ft) Hrs Before Test: Liner Lap: Pas Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N Log/SurveyEvaluation Interpretation Summary CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: N Bond Quality: Temp Survey: N Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: N Number of Remedial Squeezes: Printed: 10/1/2001 9:33:05 AM ) ) ~. ..., Phillips Alaska, Inc. Daily Drilling Report Well Sidetrack AFE 24 Hrs TMD Prog CD2-14 CD2-14 998D09 0' 7,681' Supervisor David Burley Proposed TMD 10,699' Rig Name Doyon 19 Daily Cost $170,800 Field Name Alpine Cumulative Cost $1,648,739 TVD DFS REPT NO. 7,203' 9.13 10 DATE 9/29/01 Current Status Driling ahead from Last ~afety 7851'. Meeting Event Code ODR Incident 1st 24 hrs 7No Drill 6 1/8" 24 HR Forecas h" . t I h I onzon a 0 e 9/23/01 Pressure Test(s) Type I Date I TMD I TVD I MW I Press Tot. press I EMW FIT 19/29/0117701'17203'19.6 ppglll00 psi 14,692.15 psi 12.54 ppg Last BOP Test 9/29/01 Next BOP Test 10/6/01 Last Survey 9/30/01 TMD: 8,619 INC: 90.86 Azim: 332.48 Last Casing 7 (in) @ 7671 Next Casing 4.5 (in) @ 7400 Operations Summary From To Hou rs Phase ActiVitYSUbCOdE~:me TroublEOperation ass 00:00 00:30 0.5 INTRM1 CEMENT CIRC P Circ and cond mud, final rate 7 bpm, 790 psi. PJSM. Test cement lines to 3500 psi. Pumped 20 bbls of wash and 40 bbls of 12.5 ppg spacer, cemented 00:30 02:00 1.5 INTRM1 CEMENT PUMP P casing with 31 bbls of 15.8 ppg cement. Displaced with 9.6 ppg mud using rig pumps, bumped plugs, floats held, CIP @ 0145 hours. 02:00 03:00 1 INTRM1 CEMENT PULD P RD cement head and landing joint, clear equipment from floor. 03:00 04:00 1 INTRM1 CASE PTCH P Pull thin wear bushig, install and test Packoff to 5000 psi. 04:00 05:00 1 INTRM1 CASE NUND P Change top pipe rams to 3-1/2" x 6", change drive sub on top drive to 4" XT-39. Install test plug and test BOPE. Tested annular Preventor to 250/3500 psi. Test pipe rams, blind rams, choke, kill, manifold, top Drive and surface 05:00 10:30 5.5 INTRM 1 WELCTL BOPE P safety valves to 250/5000 psi. Perform Accumulator test, pull test plug and install wear bushing. John Spaulding (AOGCC) witnessed BOPE tests. 10:30 12:30 2 INTRM1 DRILL PULD P MU BHA # 5. 12:30 13:00 0.5 INTRM1 RIGMNT RSRV P Service Top Drive and Traveling Block. PU 4" drill pipe, shallow test MWD @ 950'. 13:00 18:00 5 INTRM1 DRILL TRIP P Continue to PU drill pipe (60 jts.) and RIH to 6470'. 18:00 19:00 1 INTRM1 RIGMNT RSRV P Slip and cut drilling line. 19:00 20:00 1 INTRM1 DRILL TRIP P RIH, wash down from 7430', tagged cement @ 7520'. 20:00 20:30 0.5 INTRM1 CEMENT COUT P Clean out cement from 7520' to 7565', cire 15 min. 20:30 21:30 1 INTRM1 CASE DEQT P Blow down Top Drive, RU and test 7" casing to 3500 psi for 30 min. Blow down surface lines. ,""...:11 _..'- _____.L. .1:1__'- __..:_____.... __...I ..._....1-_1_ .L._ L..:S:..:SU L iN I K. }t:IVI t:1\l1 U::>HU J Ll:3U 1111', I ) l::>ö4', 1""::> {QJ 10/1'. UrllI LU' or new hole to 7 Il.)!'. 00:00 0.5 INTRM1 CEMENT FIT P Circ and cond mud for FIT. Condo mud & cmt. 7" Prod. casing. RU and test BOPE. MU BHA # 5 & RIH. Test casing to 3500 psi. Clean out cement and Drill 20' of new hole to 7701', circ for FIT test. 23:30 24 Hr. Sum: Injection 9/22/01 CD2-14 1,827 Source Total: 2,962 ,çJ;t2...:-2.4 Total for destination 29,613 Date Source Volume Destination J Mud Compan T ype M-I Non-Disp. LS Density FV Mud Data PV /VP 10se~ / 10 min / WL/HTHF MBT 30 mm Gels PH Flowline Drilling Temp Solids 67 4 9.6 41 8/17 6/11/13 7.2/13.6 17.5 9.2 Bits Bit/Run Size Manuf. T Serial Jets or TFA Deptt Date I-O-D-L-B-G-O-R ype No. In In 5/5 6.125 HU~~~S- STR386DG2K 1903819 /0.46875/0.46875/0.46875 7681' 9/29/01 0-0-- --- - ~ ,~ ) ') r-' '~ Phillips Alaska, Inc. Daily Drilling Report Well Sidetrack AFE 24 Hrs TMD Prog CD2-14 CD2-14 998D09 1,083' 8,764 ' Supervisor David Burley Proposed TMD 10,699' Rig Name Doyon 19 Da i Iy Cost $205,360 Field Name Alpine Cumulative Cost $1,854,099 TVD DFS REPT NO. 7,173' 10.13 11 DATE 9/30/01 Current Status Drilling ahead at 9147' . Event Code ODR Drill 6 1/8" 24 HR Forecas~ . t I h I 10nzon a 0 e Last Safety Meeting Incident 1st 24 hrs 7No 9/30/01 Pressure Test(s) Type I Date I TMD I TVD I MW I Press I Tot. press I EMW FIT 19/29/0117701'17203'19.6 ppglll00 psi 14,692.15 psi 112.54 ppg Last BOP Test 9/29/01 Next BOP Test 10/6/01 Last Survey 9/30/01 TMD: 8,619 INC: 90.86 Azi m: 332.48 Last Casing 7 (in) @ 7671 Next Casing 4.5 (in) @ 7400 Operations Summary From To Hours Phase ActivitySubcodE Tcilme TroublEOperation ass 00:00 01:30 1.5 INTRMl CEMENT FIT P CBU, perform FIT to 12.5 ppg EMW. Drill from 7701' to 8764' (7173' TVD) . ART=12.3 AST=2.8 Pumped 25 bbl 180 FV sweep @ 8120' and 20 bbl 300 FV sweep @ 8526', slight increase in cuttings with sweeps. 01:30 00:00 22.5 PROD DRILL DRLH P 24 Hr. Sum: Perform FIT to 12.5 ppg EMW. Drill 6-1/8" hole from 7701' to 8764'. Surveys MD Incl. Azimuth TVD N/S Cum E/W Cum V. Section DogLeg Build Deg/l00' 7,758.00 92.13 333.66 7,204.72 1,001.51 211.39 783.43 5.6 5.07 7,855.00 92.3 329.89 7,200.97 1,086.90 165.56 880.34 3.89 0.18 7,949.00 92.92 331.98 7,196.69 1,168.97 119.94 974.23 2.32 0.66 8,046.00 91.57 332.29 7,192.89 1,254.65 74.64 1071.15 1.43 -1.39 8,140.00 92.33 333.95 7,189.69 1,338.45 32.17 1165.07 1.94 0.81 8,236.00 91.06 331.51 7,186.85 1,423.73 -11.79 1261.01 2.86 -1.32 8,331.00 91.34 332.27 7,184.86 1,507.51 -56.54 1355.98 0.85 0.29 8,427.00 91.89 332.47 7,182.16 1,592.52 -101.05 1451.94 0.61 0.57 8,523.00 92.33 333.46 7,178.62 1,677.97 -144.65 1547.86 1.13 0.46 8,619.00 90.86 332.48 7,175.95 1,763.45 -188.26 1643.8 1.84 -1. 53 Injection Date Source Volume Destination Total for destination 9/22/01 CD2-14 1,827 Ç.D2.::24 29,613 Source Total: 2,962 ) ) J Mud Compan T ype M-I Non-Disp. LS Mud Data PV /VF 10se~ / 10 min / WL/HTHF MBT 30 mm Gels 10/ 24 11/13/13 3.4 / 8 1.2 9.2 Density FV PH 9.2 50 Bit/Run Bits Size Manuf. T Serial Jets or TFA Deptt Date ype No. In In 6.125 HU~~~S- STR386DG2K 1903819 /0.46875/0.46875/0.46875 7681' 9/29/01 5/5 ~. Flowline Drilling Temp Solids 94 1.3 I-O-D-L-B-G-O-R 0-0-- --- - ,~ Well Name: CD2-14 CASING TEST and FORMATION INTEGRITY TEST Date: 9/29/01 Supervisor: D. Burley Reason(s) for test: o Initial Casing Shoe Test o Formation Adequacy for Annular Injection o Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Setting Depth: Casing Size and Description: 9 5/8" 36# J-55 BTC X 7" 26# L-80 BTMC Mud Weight: 2,454' TMD 2,331' TVD Toe Hole Depth: 6,922' TMD 6,797' TVD 9.6 ppg Length of Open Hole Section: 4,468' EMW = Leak-off Press. + Mud Weight 0.052 x TVD = 724 psi 0.052 x 2,331' + 9.6 ppg Used cement unit Ri~ pump used 900 psi 800 psi .. 700 psi .. 600 psi .~ w !5 500 psi II) II) ~ 400 psi a.. . .. 300 psi .. 200 ps i .. 100 pSI ,.,/ o pSI I o EMW for open hole section = 15.6 ppg yes #2 Pump output = bbls pumped Fluid Pumped = 10.5 bbls Fluid Bled Back = 0.0 bbls 11111111111111111111111111111~111111111 I~IME LINE I rN~ M1NUT~ TICr .......LEAK-OFF TEST ~CASING TEST .. . LOT SHUT IN TIME -"',- CASING TEST SHUT IN TIME -+-TIME LINE 10 20 30 BARRELS 40 50 NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above Modified by Scott Reynolds LEAK-OFF DATA I MINUTES FOR LOT BBLS PRESSURE 1~~~~~~~~~]~~~~1i~~~~I~~f.~;i~~J ! ! 1.5 ! 25 psi ! [~~~~~~~~~E~~~li~~~~r~II!~~~J I I 3.5 I 86 pSI I r~~==~~~~~~~~~¡~~~~~~~º~~~~~~C~~~~~E~~~~~~ I I 4.5 I 167 pSI I t~~==~~~~~~~~~t~~~=~~~~~~~~~t~~~~~~~~~~~~i r~~=~~~~~~~~~¡~~~~~~~~~~~~~~~~~~?~~ë~~~~~~ I I 6.5 I 540 pSI I t~~~=~~~~~~~~~~r~~~~~~~~~~T~~~;f~tF~i r~~~~=~~~~~~~~~r~~~~~~º~~~~~~~~~~~?~~ë~~~~~ I I 8.5 I 555 pSI I t~~==~~~~~~~~~t~~~~~g~~~~~~~t~~~~~~~~1~~~i t~~~~~~~~~~~~~~~I~~~~i~~~~~~~~t~~~i~~~~;~~~~j I I I I I I I I ._______________.... I i ! ¡ ! ¡ i SHUT IN TIME ; SHUT IN PRESSURE ~:~~=~H:::==:=::::I:~~:~:] I 2.0 mrn I I 444 pSI I r---IO-ñi-in--T---------------r---4j-s-psl---1 1:::H:~~::E:::=::::::E~~t~I~ : 6.0 mrn : I 419 pSI : !~;~t~f.~~I::~~~~~~~~~Tlä~~~~j 60 .PHlllIPS Alaska, Inc. ~ A SLbsidiary of PHILLIPS PETROLEUM COMPANY CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE !~~~~~~~~I~~~~~~~~~~I~~~~~~~~~j ¡~~~~~~~~~~g~~~~~~~~~~g~~~~~~~~~~~1 ¡~~~~~~~~~~~l~~~~~~~~~~g~~~~~~~~~~~ 1~~~=~~~~~~f~~~~~~~1~~~~~~~~~~~ ~:::=:::::::::t=:~~:::t:::::=:::: i I ~ I ¡ SHUT IN TIME ¡ SHUT IN PRESSURE t~~~º~Q~~~~~~!~~~~~~~~~~~~~~¡~~~~~º~Ë~I~~~~1 : 1.0 mln I I I r---2~O-mìn--T--------------T----------------l r---3~o-ñïln--T--------------T----------------T ¡=:t~rH:::::=:=::::E=:::::::::::¡ I 6.0 mrn I I I r---7~õ-ñïln--T--------------T----------------! !:::~:~J~:£::::::=::::!:=::::::=:::::I : 10.0 mrn I : I r--1-š:õ-ñi 1ñ--T--- -----------T - ---- -----------1 Hl~:~¡H:::::=::::::E::::=:=::::! t__~_º~º_~!~_l______________l________________l '--' ''""-'" NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY r'" ".. , '" ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon Suspend _ Alter casing _ Repair well_ Change approved program _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at su rface 1954' FNL, 1516' FEL, Sec. 2, T11 N, R4E, UM At top of productive interval 802' FNL, 1537' FWL, Sèc. 12, T11 N, R4E, UM At effective depth At total depth 1347' FSL, 2071' FEL, Sec. 12, T11 N, R4E, UM 12. Present well condition summary Total depth: measured true vertical 12651 7228 EHective depth: measu red true ve rtical 12651 7228 Casing Conductor Surface Length 78' 2617' Size 1611 9-5/811 Production 9085' 7" Perforation depth: measu red None true vertical None - - Operational shutdown _ Plugging _ Pull tubing _ 5. Type of Well: Development _X Exploratory _ Stratigraphic _ Service Re-enter suspended well _ Time extension Stimulate Variance Perforate 6. Datum elevation (DF or K8 feet) RKB 52 feet 7. Unit or Property name Other _X 1 Annular Disposal . Colville River Unit 8. Well number CD2-39 9. Permit number I approval number 201-160 10. API number 50-103-20387 11. Field I Pool -..... Per APD Colville River Field I Alpine Oil Pool ----- Per APD feet Plugs (measured) feet Junk (measured) feet feet Cemented: 10 yds poi1la:nd 3 ready mix cmt 405 Sx A~, III L & 230 SX 15.8 class G 145 Sx 15.8 class ß Tubing (size, grade, and measured depth 3.5" 9.3#, L-80 @ 8774' MD Measured Depth 115' 2654' True vertical Depth 115' 2370' 9122' 7228' ~]:;( l::' ~:: E:' ; SEP 2 ? ZaGl A/;¡sl~a Oil .~ G~' ,., ., C. <:i~ 00ns í"~ '" . .:h h . -'.,¡ IllÎì!.'Jsì(::", . ".C ,cr?'ge 1 Packers & SSSV (type & measured depth) 7" Baker SAB-3 Permanent Packer @ 8682' MD, Camco TRM-4E @ 2206' MD 13. Attachments Description summary of proposal _ Detailed operations program _ BOP sketch Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets, schematic _X 14. Estimated date for commencing operation 15. Status of well classification as: October 4, 2001 16. If proposal was verbally approved Oil_X Gas Suspended_ Name of approver Date approved Service - 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I App~v.!1 no. ( Plug integrity _ BOP Test Location clearance _ ~)I ~ Q Mechanical ,nn _ Su eque.lfmm required 10- ;Q~""ù\a ~~<;.~~ \ Approved by order of the commiSSi~n~ 7 Commissioner Date ¡ 0 I 0 '7. ò I OUPLl CJ-\TE Signed L1./ ¿ ()l,(... Chip Alvord ~ Form 10-403 Rev 06/15/88 · --.---.. ...-.,.... -.-...... -. -. - ...-------.---... -.----- Titte: Alpine Drilling Team Leader Questions? Call Vem Johnson 265-6081 Date y ( L+ { 0 \ SUBMIT IN TRIPLICATE ') _PHILLIPS Alaska Inc m A Subsidiary of PHilliPS PETROlEUM'COMPAN; Casing Detail ~",?Jª.~f ,S U rffJç~ . Cª$.!n.g Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Jts 3 to 61 59 Jts Doyon 19 RKB to Landing Ring FMC Gen V Hanger 9-5/8" 36# J-55 BTC Csg Davis Lynch Float Collar 9-5/8" 36# J-55 BTC Csg Davis Lynch Float Shoe Jts 1 to 2 2 Jts ) TO 12 1/4" Surface Hole RUN TOTAL 35 BOWSPRING CENTRALlZERS- 1 per jt on Jt #1 . #13 (On stop rings of Jt #1 & #2) and over collars on jts# 15,17,19,21,23,25,27,29,31 33,35,37,39,41,43,45,47,49,51,53,55. Use Best-a-Life 2000 pipe dape Remarks: Up Wt - 165k Dn Wt - 137k Block Wt - 70k Well: Date: LENGTH 36.85 2.95 2524.09 1.54 86.93 1.75 Supervisor: David P. Burley CD2-39 9/4/01 DEPTH TOPS 36.85 39.80 2563.89 2565.43 2652.36 2654.11 2663.00 ) t;~S\ ~ PHILLIPS ALASKAING. Cementing Report Legal Well Name: CD2-39 Common Well Name: CD2-39 Event Name: ROT - DRILLING Report #: Start: 1 8/29/2001 Cement Job Typð: Primary Hole Size: TMD Set: Date Set: Csg Type: Csg Size: Primary 12.250 (in) 2,654 (ft) 9/4/2001 Surface Casing 9.625 (in.) Squeeze Casing Hole Size: TMD Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: Cementer: Jerry Culpepper Squeeze Open Hole Hole Size: sa TMD: (ft) sa Date: sa Type: Cmtd. Csg: OPEN HOLE Cmtd. Csg: ) Page 1 of 3 Spud Date: 8/31/2001 Report Date: 9/4/2001 End: Plug Hole Size: Top Set: (ft) BTM set: (ft) Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Pipe· Movement Pipe Movement: Reciprocating Cement Co: Dowell Schlumberger Rot Time Start: : Rec Time Start: 12:30 Time End: Time End: 16:25 RPM: SPM: Init Torque: (ft-Ibf) Stroke Length: 25.0 (ft) Avg Torque: (ft-Ibf) Drag Up: 165 (Ibs) Stage No: 1 of1 Max Torque: (ft-Ibf) Drag Down: 137 (lbs) Type: Cement Casing Start Mix Cmt: 15:02 Disp Avg Rate: 9.50 (bbl/min) Returns: Full Volume Excess %: 150.00 Start Slurry Displ: 15:04 Disp Max Rate: 10.00 (bbl/min) Total Mud Lost: (bbl) Meas. From: Start Displ: 16:09 Bump Plug: Y Cmt Vol to Surf: (bbl) Time Circ Prior End Pumping: 16:30 Press Prior: 500 (psi) To Cementing: 2.00 End Pump Date: 9/4/2001 Press Bumped: 1,000 (psi) Ann Flow After: N Mud Circ Rate: 420 (gpm) Top Plug: Y Press Held: 2 (min) Mixing Method: Mud Circ Press: 550 (psi) Bottom Plug: Y Float Held: Y Density Meas By: Densomiter Type: Spud Mud Density: 9.7 (ppg) Visc: 54 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type: Mud PVIYP: 16 (cp)/19 (lb/100ft2) Gels 10 sec: 10 (lb/100ft2) Gels 10 min: 15 (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: 9.7 (ppg) Volume: 199.00 (bbl) Stage No:1 SlurryNo:10f4 Slurry Data Fluid Type: Slurry Interval: Water Source: To: (ft) Description: Biozan w/nutplug marker Cmt Vol: (bbl) Density: 8.34 (ppg) Slurry Vol: (sk) Water Vol: (bbl) Class: Yield: (ft3/sk) Other Vol: 0 FLUSH (ft) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Time Temperature: CF) Temperature: (OF) Temperature: CF) Compressive Strength 1: Compressive Strength 2: Purpose: SPACER Mix Water: (bbl) Foam Job: N Temp CF) CF) Pressure (psi) (psi) Printed: 9/8/2001 9:55:53 AM ~ ~~ ,~ ) PHILLIPS ALASKA INC. Cementing Report Legal Well Name: CD2-39 Common Well Name: CD2-39 Event Name: ROT - DRILLING Slurry Data Fluid Type: Slurry Interval: Water Source: FLUSH (ft) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Report #: Start: Stage No:1 Slurry No: 20f4 To: (ft) Description: ARCO Spacer Cmt Vol: (bbl) Density: 10.50 (ppg) Slurry Vol: (sk) Water Vol: (bbl) Temperature: (OF) Temperature: (OF) Temperature: (OF) Compressive Strength 1: Compressive Strength 2: Stage No: 1 Slurry No: 30f4 . Slurry Data Fluid Type: Lead Slurry Interval: 2,154.00 (ft)To: 37.00 (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Description: ASLite Cmt Vol: 320.0 (bbl) Slurry Vol: 405 (sk) Density: 10.70 (ppg) Water Vol: (bbl) Temperature: (OF) Temperature: ("F) Temperature: ("F) Compressive Strength 1: Compressive Strength 2: Stage No: 1 Slurry No: 40f4 Slurry Data Fluid Type: TAIL Description: G + Adds Slurry Interval: 2,654.00 (ft)To: 2,154.00 (ft) Cmt Vol: 48.0 (bbl) Water Source: Slurry Vol: 230 (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Density: 15.80 (ppg) Water Vol: (bbl) Temperature: ("F) Temperature: ("F) Temperature: (OF) Compressive Strength 1: Compressive Strength 2: ) Page 20f 3 1 8/29/2001 Spud Date: 8/31/2001 Report Date: 9/4/2001 End: Class: Yield: (ft3/sk) Other Vol: 0 Time Temp (OF) (OF) Class: G Yield: 4.44 (ft3/sk) other Vol: 0 Time Temp ("F) ("F) Class: G Yield: 1.17 (ft3/sk) Other Vol: 0 Time Temp ("F) (OF) Purpose: SPACER Mix Water: (bbl) Foam Job: N Pressure (psi) (psi) Purpose: PRIMARY Mix Water: (bbl) Foam Job: N Pressure (psi) (psi) Purpose: PRIMARY Mix Water: (bbl) Foam Job: N Pressure (psi) (psi) Printed: 9/8/2001 9:55:53 AM ) ') ~ TfI"it ~¡ PHILLIPS ALASKA INC. Cementing Report Page 3 of 3 Legal Well Name: CD2-39 Common Well Name: CD2-39 Event Name: ROT - DRILLING Report #: Start: 1 8/29/2001 Spud Date: 8/31/2001 Report Date: 9/4/2001 End: Casing Test Shoe Test . Lirier Top Test Test Press: 2,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: N Pressure: (ppge) Tool: N Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N Log/SurveyEvaluation Interpretation. Summary CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: N Bond Quality: Temp Survey: N Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: N Number of Remedial Squeezes: Remarks Displaced cement with 20bbls of fresh water from cementers, and 179 bbls of mud with rig pumps. Displaced mud @ 10 bpm, slowed to 8 bpm after 20 bbls of tail around shoe. Reciprocated pipe untilllast 20 bbls of displacement, had 119 bbls of 10.7 ppg cement returns to surface with full returns throughout. Printed: 9/8/2001 9:55:53 AM Phillips Alaska, Inc. Daily DriHingReport I JOB NUMBER I EVENT CODE 124 HRS PROG CD2-39 ODR I RIG NAME & NO. I FIELD NAME I OCS NO. Doyon 19 Alpine ACCIDENTS LAST 24 HRS.? 24 HR FORECAST DATE OF LAST SAFETY MEETING BHA #3, MIT, clean out cmt FIT, drill 8-1/2" hole. 9/4/2001 LITHOLOGY 1 JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF LAST SURVEY: DATE TMD INC AZIM I LAST CASING 9/3/2001 2,530.00 38.530 146.230 (in) @ (ft) DENSITY(ppg) 9.60 I PP I I ECD I I MUD DATAl DAILY COST I FV PVIYP GELS WUHTHP FC/T.SOL OIL/WAT %SaridIMBT PhlpM 53 19/19 10/15 11.21 /20.0 8.0/ ) .~ Tf'f'il ~~ WELL NAME SUPERVISOR David Burley CURRENT STATUS Testinç¡ BOPE. BHANO. I 3 I BHA WT.BELOW JARS STRING WT. Lip ITEM DESCRIPTION BIT 6 3/4"MACH1XL 1.2 N MST AB GAMMA SUB MWD NEUTRON NON-MAG FLEX XO HWT JARS HWT BIT I RUN 21 SIZE MANUF. TYPE 12.250 STC HO WOB RPM GPM BIT/RUN 2/ FROM TO HOURS CODE TROUBLE SUB 00:00 01:00 1.00 DRILL T TRIP 01:00 03:00 2.00 DRILL T CIRC 03:00 06:00 3.00 DRILL T TRIP 06:00 08:00 2.00 CASE P RURD 08:00 12:00 4.00 CASE P RUNC 12:00 12:30 0.50 CASE P RURD 12:30 14:30 2.00 CASE P CIRC 14:30 16:30 2.00 CEMENT F PUMP ) Page 1 òf 2 TMD I TVD I DFS 2,663.0 2,376.0 3.00 AUTHMD DAILYTANG 0.00 DAILY INTWIO MUD 0.00 DAILY TOTAL 319,898 I REPT NO. I DATE 3 9/4/2001 I CUM. TANG 0.00 CUM INTANG WI MUD 0.00 CUM COST WI MUD 614,634 AFE AUTH. 998007 I NEXT CASING (in) @ LAST BOP PRES TEST (ft) 0.00 PflMf CUM COST Ca ES 0.00 LIME CI H2S BHA I HOLE CONDITIONS BIT NO. I 3 STRINGWT. DN STRINGWT.ROT TORQUE I UNITS BHA LENGTH 1,095.52 NOJTS LENGTH O.D. LD. CONN SIZE CONN TYPE 1 1.00 8.500 1 31.60 6.750 1 5.00 2.875 1 19.73 7.000 3.250 1 27.32 7.000 3.250 1 22.34 7.000 3.250 3 90.00 4.500 2.875 1 1.68 6.250 3.000 3 89.48 5.000 3.000 1 32.98 6.125 2.250 26 774.39 5.000 3.000 BITS· SERIAL NO. 750017 JETS OR TFA DEPTH IN DATE IN I-O-D-L-B-G-O-R 2,663.0 9/3/2001 0-0------ BIT OPERATIONS PRESS P BIT HRS 24Hr.DIST 24HrROP CUMHRSCUMDEPTH> .CUM Rap OPERATIONS SUMMARY PHASE DESCRIPTION SURFAC RIH with BNHO clean out assembly to 2663', no problems. SURFAC Circ and condition mud with 15 bpm, 130 rpm, had large amount of clay cuttings back, shakers overloaded for 20 min. Pumped 40 bb111.2 ppg sweep, circ hole clean. Monitor well, static. SURFAC POH, max overpull15k, no swabbing. LD BNHO, clean rig floor. SURFAC RU to run 9-5/8" casing, held prejob safety meeting with crew. SURFAC Ran 61 joints of 9-5/8",36#, L-80 BTM casing. Landed casing @ 2654'. SURFAC Lay down fill up tool, MU cement head. SURFAC Staged pumps up to 10 bpm 550 psi, circ and cond mud, reciprocated casing 20-25'. PJSM. SURFAC Pump 40 bbls vis.spacer, 5 bbls of FW, test cement lines to 2500 psi. Pumped 5C bbls of 10.5 ppg spacer, 310 bbls of10.7 ppg lead cement and 48 bbls of 15.8 tail cement. Displaced cement with20 bbls of FW and 179 bbls of mud. Bumped Printed: 9/5/2001 7:12:16 AM Phillips Alaska, Inc. Daily Drilling Report IJOB NUMBER IEVE;TDc~DE 124 HRS PROG IT~~663.0 ) .~ r¡r¡i ~~I WELL NAME CD2-39 FROM TO HOURS CODE TROUBLE SUB 14:30 16:30 2.00 CEMENT F PUMP 16:30 18:30 2.00 CASE P RURD 18:30 21:30 3.00 CASE P RURD 21:30 00:00 2.50 RIGMNT P RURD ') . Page 2 of 2 ITVD I DFS 2,376.0 3.00 I REPT NO. I DATE 3 9/4/2001 OPERATIONS SUMMARY PHASE DESCRIPTION SURFAC plugs to 1000 psi, floats held, CIP at 1630 hrs, had 119 bbls of 10.7 pgg cement back to surface. SURFAC Flush cement from Conductor, RD cement head, LD landing joint. PU jet sub and flush surface stack. SURFAC NO Divertor system, install wellhead and test M/M seals to 1000 psi. NU BOP stack. SURFAC Slip and cut drilling line, changed out saver sub on top drive to 4", changed out annular preventor on stack. 24 HR SUMMARY: RIHw/BNHO to 2663', circ hole clean, POH, Run and cement 9-5/8" surface casing, shoe @ 2654'. Install wellhead, NU and test BOPE. COMPANY Phillips Doyon Baker Inteq Service Personnel (GIS) Anadril SERVICE ITEM UNITS gals bbls USAGE 1,230 331 Fuel Water, Drilling TYPE NO. 1,198 CD2-39 CD2-24 PERSONNEL DATA NO. . HOURS .. COMPANY 1 Artic Catering Inc. 26 MI Drilling Fluids 1 FMC 4 APE 3 Dowell SERVICE NO~ HOURS 5 4 1 1 2 MATERIALS I CONSUMPTION ON HAND ITEM -3,145 Water, Potable -1,451 UNITS bbls USAGE 110 ON HAND -335 SUPPORT CRAFT REMARKS TYPE NO; REMARKS Printed: 9/5/2001 7:12:16 AM CASING TEST and FORMATION INTEGRITY TEST Well Name: CD2-39 Date: 9/5/01 Supervisor: D. Burley Reason(s) for test: o Initial Casing Shoe Test o Formation Adequacy for Annular Injection o Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8", 36#, J-55, BTC CSG Casing Setting Depth: 2,654' TMD Hole Depth: 2,673' TMD 2,370' TVD 2,384' TVD Mud Weight: 9.6 ppg Length of Open Hole Section: 19' EMW= Leak-off Press. + Mud Weight = 820 psi + 9.6 ppg 0.052 x TVD 0.052 x 2,370' EMW for open hole section = 16.3 ppg Used cement unit Rig pump used NO #2 Pump output = 0.0997 bps Fluid Pumped = 1.0 bbls Fluid Bled Back = 0.8 bbls w 0:: => C/) C/) W 0:: c.. 40 50 111111111 f IIIIIII LU I L!l!li.W~~~~:=~~ I~ME LINE I rN~ MINUT~ TICrS .......LEAK-OFF TEST ~ ~ CASING TEST -1 um LOT SHUT IN TIME =1 ---:~~ CASING TEST SHUT IN TIME -1 -I-T1ME LINE 20 30 STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above Modified by Scott Reynolds LEAK-OFF DATA 60 MINUTES FOR LOT STROKES PRESSURE J~~=~~~~~~~~~~~¡~~~=~~~~~~~~~C~~~~~~E~~~~~~ : : 1.0 I 50 pSI : t~~~=~~~~~~~~~r~~~~~~~~~~~r~~~~~~~tF~l r~~==~~~~~~~~~r~~~~~~º~~~~~~CJ~~~ë~~~~~~l I : 5.0 : 450 pSI : F~~=~~~~~~~~~f~~~~-;~~~~~~~~F~~~~~~tF~l r~~~~~~~~~~~~~~~¡~~~~~~~º~~~~~~C~~~~~~ë~~~~~l : I 9.0 : 760 pSI : E:==::::::::E~~!::::E:~~~~~:::¡ 1~~~~~~~~t~~~~~~~~~t~~~~~~~~~~~J !~~~~~~~~~g~=~~~~~l~~~~~~~~~~~~J t~~~~=~~~~~~~~t~~~~~~~~~~~~~t~~~~~~~~~~~~~~~j I I I I l--------------- ! ¡ J I I I I i : : I ¡ SHUT IN TIME ¡ SHUT IN PRESSURE 1:::~~:~Jß::E::=::::::::¡31~]~E:¡ I 2.0 mIn : : 750 pSI I 1~~~~~~ß~]~~~~~~~~~~~t~~ii~¡~~~j I 6.0 mln : I 720 pSI I [~~~~~~jñ~~±~~~~~~~~~~~~~~~E~~~~~~~E~j I Q 0 . I I 710 . I [~~~~~Q~~fu~t~~~~~=~~~~~~t~~I~~~~~L~j .PHlllIPS Alaska, Inc. ~ A SLbsidiary of PHilLIPS PETROLEUM COMPANY CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE [~~~~~~~~~~~~~r~~~~~!E~~~~r~~~~~ë~I~~~~1 ! I 2 stks I 20 psi I f~~~~~~~~~~~~~~~F~~~~~llit~~~F~~~~~~~~F~t [~~~~~~~~~~~~~¡~~I~!E~~~~¡~~~~Z~~p~~!~~~1 ! I 10 stks I 660 psi I ¡---------------¡-Tfstks--¡---ãsõ-ps¡---¡ r---------------rT~rstks--r-i~Õ4(rpsT1 r--------------rTS-stks--r-iJ3õ-psTl ~---------------+-------------+--------------.--t : I 18 stks I 1,420 pSI I ¡---------------¡--i-fstks--¡--i~6ÕÕ-psT¡ ¡---------------r-i-2-stks-I--(fãõ-psT1 r---------------r-2~rstks--r2~rÕÕ-psTl ~--------------+--------------+-------------_;,--t : I 26 stks : 2,350 pSI I ¡:::==::::::E!:~~~~l~~~!~:~~~::1 ¡:::==::::::t:=::=::::::r:::::::::=:::~ I ~ I I L~.!'!~!_~~_"!:~~_¡______________~.!'!I!!_~~!~~~_l:!~ ! 0.0 min I ! 2.520 psi ¡ F~~~~~~~R~~F~~~~~~~~~~~~~F~~~~~~~~Ft CIQ~~~~~~r~~~~=~~~~~~~r~~~~~~ë~~~~1 : 4.0 mm : I 2,490 pSI I r~~~~~Q~~~~~~¡~~~~~~~~~~~~~~r~~~~~~ë~~~~t : 0.0 mm : : 2,490 pSI : C~~?~Q~~~~~~r~~~~~~~~~~~~~¡~~~~~~~ë~~~~1 I 8.0 mm I I 2,480 pSI: f~~~~6~~r~~F~~~~~~~~~~~~~F~~~~~~~tFt ¡:~~~:~¡H:::::::::::::EH~H~::¡ : ¿5.0 mln : : 2,470 pSI I [~~~~º~Q~~I~I~~~~~~~~~~~~~~I~~~?~~ë~JJ --- ~ NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ) ) Casing Detail r:Jnt.?r.me(J.iate Çasing Well: Date: ARca Alaska, Inc. Subsidiary of Atlar Subsidiary of Atlantic Richfield Company Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Jts 3 to 222 Jts 1 to 2 Remarks: LENGTH Doyon 19 RKB to LOS FMC 11" X 7" Hanger 220 Jts 7" 26# L-80 BTCM Csg 7" Davis Lynch Float Collar 2 Jts 7" 26# L-80 BTCM Csg 7" Davis Lynch Float Shoe 35.12 2.22 9003.73 1.42 78.28 1.70 1 straight blade centralizer per jt #1-#20 1 spiral blade centralizer every other jt. #160-#220 51 Total Use Best-a-Life 2000 pipe dope Up Wt = 300k On Wt = 170k Block Wt= 80k Supervisor: David Burley CD2<39 9/13/01 DEPTH TOPS 35.12 37.34 9041.07 9042.49 9120.77 9122.4 7 ~ lIfu ) PHILLIPS ALASKA INC. Cementing<Report Legal Well Name: CD2-39PB1 Common Well Name: CD2-39PB1 Event Name: ROT - DRILLING Primary Hole Size: 8.500 (in) TMD Set: 9,122 (ft) Date Set: 9/13/2001 Csg Type: Intermediate Casing/Li Csg Size: 7.000 (in.) Cmtd. Csg: OPEN HOLE Cement Co: Dowell Schlumberger Rot Time Start: Rec Time Start: Time End: Time End: Type: Pre-Flush Volume Excess %: Meas. From: Time Circ Prior To Cementing: 3.25 Mud Circ Rate: 294 (gpm) Mud Cire Press: (psi) Report #: Start: 2 8/29/2001 Cement Job Type: Primary · Squeeze Open Hole Hole Size: sa TMD: (ft) sa Date: sa Type: Squeeze Casing Hole Size: TMD Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: Cmtd. Csg: ) Page 1 of 2 Spud Date: 8/31/2001 Report Date: 9/13/2001 End: 9/20/2001 Plug Hole Size: Top Set: (ft) BTM set: (ft) Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Pi pe Movement Pipe Movement: Reciprocating Cementer: Jim Thompson RPM: SPM: Init Torque: (ft-Ibf) Stroke Length: 25.0 (ft) Avg Torque: (ft-Ibf) Drag Up: (Ibs) Stage No: 1 of 1 Start Mix Cmt: Start Slurry Displ: Start Displ: End·Pumping: End Pump Date: Top Plug: Y Bottom Plug: Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 7.75 (bbl/min) 8.00 (bbl/min) Y 595 (psi) 1,000 (psi) (min) Y Mud Data Max Torque: (ft-Ibf) Drag Down: (Ibs) Returns: Total Mud Lost: (bbl) Cmt Vol to Surf: (bbl) Ann Flow After: N Mixing Method: Density Meas By: Type: Non-Disp. LS Density: 9.6 (ppg) Vise: 44 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type: PV/yP: 11 (cp)/24 (lb/100ft2) Gels 10 sec: 7 (lb/100ft2) Gels 10 min: 9 (lb/100fF) Bottom Hole Static Temperature: (OF) Density: (ppg) Volume: (bbl) Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Stage No:1 Slurry>No: 1of2 To: (ft) Description: 50 bbls 12.5 ppg Class: Cmt Vol: (bbl) Density: 12.50 (ppg) Yield: (fP/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Purpose: SPACER Mix Water: (bbl) Foam Job: N Temp CF) (OF) Pressure (psi) (psi) Printed: 9/27/2001 8:31:07 AM ) ) ~~. ~ ~ PHILLIPS ALASKAINC~ Cementing Report Page 2 of 2 Legal Well Name: CD2-39PB 1 Common Well Name: CD2-39PB1 Event Name: ROT - DRILLING Report #: Start: 2 8/29/2001 Spud Date: 8/31/2001 Report Date: 9/13/2001 End: 9/20/2001 Stage No: 1 Slurry NO:2of2 SI urry Data Fluid Type: PRIMARY Description: Slurry Interval: 9,122.00 (ft¡To: 8,375.00 (ft) Cmt Vol: 30.0 (bbl) Water Source: Slurry Vol:145 (sk) Class: G Density: 15.80 (ppg) Yield: 1.15 (ft3/sk) Water Vol: (bbl) Other Vol: 0 Purpose: PRIMARY Mix Water: (bbl) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) Casing Test Shoe Test Liner Top Test Test Press: 3,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: Y Pressure: 12.50 (ppge) Tool: N Open Hole: 20 (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N Log/Survey Evaluation Interpr~tationSummary CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: N Bond Quality: Temp Survey: N Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: N Number of Remedial Squeezes: Remarks Pumped 20 bbls of ARCO wash, 50 bbls of 12.5 ppg spacer and 30 bbls of 15.8 ppg cement. Displaced with 20 bbls of FW from cementers and 327 bbls of mud at 8 bpm using rig pumps. reciprocated casing 20-25' untilllast 30 bbls of displacement. Bumped plugs to 1000 psi, floats held. Maintained full returns throughout, CIP at 1117 hours 09/13/2001. Printed: 9/27/2001 8:31:07 AM ) ~ (~ ~¡ Phillips Alaska, Inc. Daily Drilling Report I JOB NUMBER I EVENT CODE 124 HRS PROG TMD I TVD I DFS CD2-39 ODR 9,132.0 7,228.0 12.00 I RIG NAME & NO. I FIELD NAME I OCS NO. AUTH MD I DAILY TANG Doyon 19 Alpine 12,672.0 0.00 ACCIDENTS LAST 24 HRS.? DAILY INTWIO MUD 0.00 DATE ~F LAST SAFETY MEETING DAILY TOTAL 9/13/2001 275,365 I LEAKOFF AFE 16.20 998007 I NEXT CASING 2,654.0 (ft) 7.000 (in) @ WELL NAME SUPERVISOR David Burley CURRENT STATUS RIH with BHA # 5. 24 HR FORECAST RIH, test csg, drill out cmt, FIT, Drill 6-1/8" horz. hole. LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP LAST SURVEY: DATE TMD INC AZIM I LAST CASING 9/11/2001 9,069.00 82.810 150.670 9.625 (in) @ DENSITY(ppg) FV PV/yP 48 9/26 9.60 I PP I GELS WLlHTHP 10/12 4.8/9.8 IECDI I MUD DATAl <DAILY COST. I FC/T;SOL OIL/WAT %S~mdiMBT . Ph/pM I I /16.2 9.5/ .BHANO. I 5 BHA WT. BELOW JARS 0.00 Pf/Mf / STRING WT. UP BHA I HOLE CONDITIONS STRING WT. DN STRINGWT. ROT ITEM DESCRIPTION BIT TURBO-BACK STAB MOTOR MACH 1X-AKO NMSTAB SNM FLEX COLLAR MWD ANNULAR PRESSURE NEUTRON-ADN N M FLEX COLLARS XO HWDP JARS HWDP NO JTS 1 1 1 1 1 1 1 1 3 1 3 1 2 LENGTH 0.85 0.85 21.87 3.70 10.51 35.22 15.20 25.09 93.11 1.19 91.99 32.43 61.34 FROM TO 00:00 02:00 02:00 02:30 HOURS 2.00 0.50 TROUBLE SUB RUNC CIRC OPERATIONS SUMMARY PHASE INTRM1 INTRM1 CODE CASE P CASE P 02:30 04:30 2.00 CASE P RUNC INTRM1 04:30 05:15 0.75 CASE P CIRC INTRM1 05:15 07:30 2.25 CASE P RUNC INTRM1 07:30 08:00 0.50 CASE P RURD INTRM1 08:00 09:45 1.75 CEMENT P CIRC INTRM1 09:45 11 :30 1.75 CEMENT P PUMP INTRM1 11:30 12:30 1.00 CEMENT P 12:30 15:00 2.50 CASE P 15:00 16:00 1.00 CASE P 16:00 22:00 6.00 WELCTL P INTRM1 INTRM1 INTRM1 INTRM1 PULD PTCH RURD BOPE a.D. 6.125 6.094 6.000 6.125 4.750 5.250 4.750 5.875 4.625 5.250 4.000 4.750 4.000 ) Page 1 of 2 I REPT NO. I DATE 12 9/13/2001 ICUM. TANG 0.00 CUM INTANG WI MUD 0.00 CUM COST WI MUD 1,961,285 AUTH. LAST BOP PRES TEST 9/13/2001 (ft) I CÙMCOSTI CI ·Ca 0.00 LIME H2S ES TORQUE! UNITS BITNO·I 5 . BHALENGTH 393.35 CONN SIZE CONNTYPE tD. 2.375 2.375 2.120 2.120 2.500 2.375 2.500 2.562 2.250 2.562 DESCRIPTION Run 7" casing to 5108'. Stage pumps up to 7 bpm, 640 psi, Circ BU, cond mud. PUW 190k SOW 142k. Run casing to 7201'. Stage pumps up to 7 bpm, 960 psi, CBU and cond mud. POW 240k SOW 150k. Run casing, MU hanger and landing joint, land casing with shoe @ 9122'. LD fill up tool, MU cement head. Staged pumps up to 7 bpm, cond mud for cementing, final circ pressure 730 psi, reciprocated casing throughout. PJSM. test lines to 3500 psi, pump 20 bbls of chemical wash, 50 bbls of 12.5 ppg spacer and 145 sxs of 15.8 ppg G cement with adds. Displace cement with 20 bbls of FW and 327 bbls of 9.6 ppg mud. Bumped plubs to 1000 psi, floats held. CIP @ 1117 hrs, bleed off to check floats, held. Monitor well, static. LD cement head and landing joint. Pull thin wear bushing, install and test packoff to 5000 psi, 10 min. Change top pipe rams to 3-1/2" x 6", change top drive saver sub to 4" XT. Install test plug in wellhead, test BOPE. test Annular to 250/5000 psi. Test Printed: 9/17/2001 9:43:14 AM ~ @ WELL NAME FROM TO 16:00 22:00 22:00 00:00 CD2-39 ) HOURS 6.00 CODE TROUBLE SUB WELCTL P BOPE 2.00 DRILL P PULD PhiUipsAlaska,lnc. Daily Drilling> Report 1 JOB NUMBER 1 EVE;TDC~DE 124 HRS PROG 1 T~~132.0 ) Page 2 of 2 IrvD 1 DFS 7,228.0 12.00 I REPT NO. 1 DATE 12 9/13/2001 OPERATIONS SUMMARY PHASE DESCRIPTION INTRM1 pipe and blind rams, choke, kill, manifold, Top drive and surface safety valves to 250/5000 psi. Perform Accumulator test, pull test plug and install wear bushing. INTRM1 PU M1XL motor, MWD and LWD, MU BHA #5, install source in NUE/DEN tool. PERSONNEL DATA NO. HOURSCOMPÄNV 1 Anadril 23 Artic Catering Inc. 1 MI Drilling Fluids 4 Dowell MATERIALS I CONSUMPTION ON HAND ITEM -1,798 Water, Potable -3,873 SUPPORT CRAFT REMARKS TYPE 24 HR SUMMARY: Ran 7" casing, cond mud and cement casing landed with shoe @ 9122'. CIP @ 1117 hrs. RD, install and test packoff to 5000 psi. Test BOPE, MU BHA #5. COMPANY Phillips Doyon Baker Inteq Service Personnel (GIS) ITEM SERVICE UNITS gals bbls NO. CD2-39 USAGE 678 84 SERVICE NO~ HOURS 2 5 4 2 Fuel Water, Drilling TYPE CD2-24 UNITS bbls USAGE 110 ON HAND -1,315 NO. REMARKS Printed: 9/17/2001 9:43:14 AM Well Name: CD2-39 CASING TEST and FORMATION INTEGRITY TEST Date: 9/14/01 Supervisor: D.Burley Reason(s) for test: o Initial Casing Shoe Test o Formation Adequacy for Annular Injection o Deep Test Open Hole Adequacy for Higher Mud Weight Casing Setting Depth: Casing Size and Description: 9 5/8" 36# J-55 BTC X 7" 26# L-80 BTMC Mud Weight: 2,654' TMD 2,370' TVD TOC Hole Depth: 8,375' TMD 6,857' TVD 9.7 ppg Length of Open Hole Section: 5,721' EMW = Leak-off Press. + Mud Weight 0.052 x TVD = 722 psi 0.052 x 2,370' + 9.7 ppg Used cement unit Riq pump used 900 psi 800 psi 700 psi ~ I 600 psi (I W ~ 500 ps i .. :J en . en w 400 psi ~ a.. ~ I 300 psi - . 200 psi -., 100 psi 7 t. o psi I 0 II ! EMW for open hole section = 15.6 ppg yes Pump output = bbls pumped Fluid Pumped = 11.5 bbls Fluid Bled Back = 0.0 bbls 111111111111111111111111I11r~111111111 IIIME LINE I r~~~~r~~'tl§¡ ...... LEAK-OFF TEST """'IP- CASING TEST . . -LOT SHUT IN TIME ....-,:.é- CASING TEST SHUT IN TIME -+-TIME LINE ...."I!. 10 20 50 30 BARRELS 40 NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above Modified by Scott Reynolds LEAK-OFF DATA 60 MINUTES FOR LOT BBLS PRESSURE ..----------- -----.---------------r----------------~ : : 0 : 0 psi : [~~~~~~~~~~~~~~~¡~~~]~~¡I¡1~~~j : : 2.0 I 40 psi : !~~~~~~~~~~~~~~~!~~~~~~~~~~~~~t~~~~~Ië~~~~~~~ I I 3.0 I 75 pSI : r------------I-----3~S------r---;¡15-j>Š-f--l r~~=~~~~~~~~~~~¡~~~~~~~~~~~~~~~~~~If~~ë~~~~~] I : 4.5 I 225 pSI : F~~=~~~~~~~~~F~~~~~~~~~~~~~F~~~~~~~~~~i r~~==~~~~~~~~~¡~~~~~~~~~~~~~~~~~~~?~~~ë~~~~~] : : 6.5 I 490 pSI I f~~~~=~~~~~~~~~f~~~~~~~~~~~~~f~~~~~~~~~~~~i r~~~~~~~~~~~~~~~¡~~~~~~º~~~~~~~~~~~?IR~~~~~] I : 8.5 I 722 pSI I F~~~=~~~~~~~~f~~~~~;~~~~~~~~F~~~~~~~~~~i r~~~~~~~~~~~~~~~¡~~~~1~~º~~~~~~~~~~~~~R~~~~~] I : 10.5 I 590 pSI : ¡---------------y----·:¡;ì:õ-----¡---6'õõ-j>šT-1 r--------------, 11.5 ! 61 0 Ps i ! I I I I i SHUT IN TIME ¡ SHUT IN PRESSURE [t~:~g:£:::==::::]:::I~r~~:::J : 2.0 mIn : I 520 pSI I 1~~lli~~~~~~~~~~~~I~ill~~~~1 I 7.0 min I I 470 psi : i~~~?~~º~~~~~t~~=~~~~~~~~~t~~~~~~R~~~~1 I Q 0 . I I 454 . I f~~~~º~Q~~fkt~~~~~~~~~~~~~t~~~~~~;Lj .PHlllIPS Alaska, Inc. ~ A SLt:>sidia¡y of PHILLIPS PETROLEUM COMPANY CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE E=:::=:::::E~:~~J:::~:~~::] : I I I ~~~~~~~~~~~~~~~~+~~~~~~~=~~~~~+~~~~~~~~~~~~~~~~I F::=::::::r:::=:::::::f:::::::=::::::: r---------------T--------------T----------------T f:~~~~~~~~~~~l~~~~~~d~~~~~~~~~~~~~ ~:::::=:::::f~::~~::::r:::::::::::::::¡ r--------------T--------------T----------------T t::=:~~::::::t::::=:=::l::::::~~::::: ~ i : I : SHUT IN TIME ; SHUT IN PRESSURE [~~~~jR~l~~~~~~~~[~~~~~~] : 3.0 min : : I 1]~:~Jgl::::::=:::::!::::::::=:::::: ; 6.0 mln I I I r-----------:- ---T--------------T-.. ------------ --, I 7.0 mln I : I 13f~JH::::::::::::=E::::==:::::1 : 10.0mH1 : : I r-----------7-- -..,.--------------- "T'"----------------T I 15.0 mln : : I !~I&I~~¡~J~~~~~~~~~~~r~~~~~~~~~~~j .---- _/ NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSl\fiTT AL LETTER WELL NAME (],g~t- (!¡)2~¥S- CHECK 1 STANDARD LETTER DEVELOPMENT / DEVELOPMENT RED RILL EXPLORA TION INJECTION WELL INJECTION WELL REDRILL CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-(9) PILOT HOLE (PH) ANNULAR DISPOSAL <--JNO ANNULAR DISPOSAL ( ~YES ANNULAR DISPOSAL THIS WELL DISPOSAL INTO OTHER ANNULUS dYES + SP ACING EXCEPTION Templates are located m drive\jody\templates "CLUE" The permit is for a new wellbore segment of existing well -'--' Permit No, . API No. . Production should continue to be reported as a function of tbe original API number stated above. . In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . . 1/ I /-' ""//- þL-././ / , p- tU!.<Jd- -#,'c'l.""-- LZJZ - 'r'':::''1fPe-rn,.-( '- ' 'I<d , j:;P z5",,Ltu...- ~U~ dUG("'5d r~~ , Annular Disposal of drilling wastes will not be approved. . . Please note tbat an disposal of fluids generated.. . f7u,;), ~ k.. ~'L~ t-ll:f¿, ~ ¿;L--v-\.-r'lv'!u..'I. ð'yt .. ê-D2. ~ Enclosed is the approved application for permit to drill tbe above referenced well. The permit is approved ,subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume tbe liability of any protest to the spacing exception that may occur. [? /êl( WELL PE RMIT CHECKU~T COMP ANY fl:J /1/5. WELL NAME {!P 2 - 0- PROGRAM: exp _ ~ev ./ redrtl_ serv _ wellbore .seg _ann. disposal para req _ FIELD & POOL /2U I C)-C) INIT CLASS' ~ t/ 1 01 L- GEOL AREA ffl¡;~ UNIT# (25C:.>..:30(;' ON/OFF SHORE 01 ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . '{ N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . _ N 3. Unique well name and number. " . . . . . . . . . . . . . . . N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . " N 5. Well located proper distance from drilling unit boundary. . N 6. Well located proper distance from other wells.. . . . . . 7. Sufficient acreage available' in drilling unit.. . . . . . . . . . . 8. If deviated, is wellbóre plat included.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . APPR DATE ~ 12. Permit can· be issued without administrative approval.. . . . . _u ft> IDo"?t' It;. 13. Can permit be approved before 15-day wait.. . . . . . . . . . é:c;NEERING 14. Conductor string provided ., . . . . . . " . . . . . . . . . 15. Surface casing protects all known USDWs. . . . . . . . . . . 16. CMT vol adequate to circulate on conductor & surf csg. . . . . 17. CMT vol adequate to .tie-in long string to surf csg. . . . . . . . 18. CMT will cover all known productive horizons. . . . . '. . . . . 19. Casing designs adequate for C, T. B & permafrost. . . . . . . 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 21. If a re-drill, has a 10-403 for abandonment been approved. . . 22. Adequate wellbore separation proposed.. . . . . . . . . . . . 23. If diverter required, does it meet regulations . . . . . . . . . . 24. Drilling .fluid program schematic & equip list adequate. . . . . 25. BOPEs. do they meet regulation . . . . . . . . . . . . . . . . 26. BOPE press rating appropriate; test to ~'Ç()'ë} \',,~ psig. 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 28. Work will occur without operation shutdbwn. . . . . . . . . . . 29. Is presence of H2S gas probable.. . . .. . . . . . . . . . . . 30. Permit can be issued wlo hydrogen sulfide measures. . . . . /Y) N 31. Data presented on potential overpressure zones . . . . . . . "-1 y" 32. Seismic anal~~is of shallo~ gas zones. . . . . . . . . . . .. ¡J'Ax' N AP~ DATE ( 33. Seabed condition survey (if off-shore). . . . . . . . . '.r~'~ Y N I ../JO /0 ':;D'C> 34. Contact name/phone for weekly progress reports [explo~'T only) Y N . ANNULAR DISPOSAL35. With proper cementing records. this plan . (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate frèshwater; or cause drilling waste. .. to surface; . (C) will not impair mechanical integrity pf the well used for disposal; Y N (0) will not damage producing fonnation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING:' UIC/Annular COMMISSION: ~þ~ +~;;J~/t( \y~ -9g~/I~ / '!lb/ò1 .~ ~fì1;-c GEOLOGY APPR DATE c:\msoffice\wordian\diana\checklist (rev. 11/01/100) ~u..r-f46L I¢c~-h6~ ~ '~iP ~oduc-"¿¿'-<- ;~~..:·krvLl../ ~ Api- 38DD7bj ~ D. ~ 'l1-VL- o¿5s3;1 N. N N N ." N N Y N . ~~ -v.; ~.{"'1k.. gwð;,...p .LJu",1-- ,"'- C1/v,;.1{ ß'-<- dJ h y ® ~~~~~~~~~~s.c..\~~",,~ C'\ . y (NJf')'\'ê~ ~'« (,c",}'M~\<t-\\~~ ~\~,,~~ \ . ~ ~ ~~....~...\~I f\{\ '0t~~""([ ~\-~ <0- ~ ~\C,>~ C-~~\~\C:..~~ \~)~~~\\t~ "~'t\C) ~~~\\~\"t\\¿è) N ~ \--\J$\,~-\<L;r.;d'~, ~\,ç\~~-\ \~'l ~~~ Y~ c 0 Z 0 .( -t \ :E ;0 -t m Z -t J: en > ;0 m .,( » Y N Y N <:..~ "'"...'::? ->.c--. '1>,," ~~ ~ ~ \.-... ~"'~ ~~ ~\(:' Q. "''' ù\",::,.. ~~~~~"\~~su.\ ~\\\~\'i ~\~"'1"-~ , Commentsllnstructions: ) ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accunlulated at the end of the file under APPEN,DIX. No special effort has been made to chronologically organize this category of information. . . Sperry-Sun Dri. )ng Services LIS Scan Utility ') 201 -2.12 11 E>~ $Revision: 3 $ LisLib $Revision: 4 $ Mon Jun 02 13:54:14 2003 Reel Header Service name..... . . . . . . . .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 03/06/02 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name..... . . . . . . . .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 03/06/02 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Colville River Unit (Alpine) MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA CD2-45 501032039500 Phillips Alaska, Inc. Sperry Sun 10 -APR- 03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MW-22201 R. KRELL D. MICKEY MWD RUN 3 AK-MW-22201 M. HANIK D. MICKEY MWD RUN 4 AK-MW-22201 R. KRELL G. WHITLOCK # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 2 11N 4E 2013 1509 .00 52.70 15.90 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 2764.0 6.125 7.000 9972.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NÒTED. ~) ) 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY AND IS NOT PRESENTED. 4. MWD RUNS 2 - 3 WERE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) , UTILIZING GEIGER-MULLER TUBE DETECTORS¡ ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) ¡ AND PRESSURE WHILE DRILLING (PWD). 5. MWD RUN 4 WAS DIRECTIONAL WITH DGR¡ EWR4¡ PWD¡ AND AT-BIT INCLINATION (ABI). 6. MWD IS CONSIDERED PDC PER THE DISCUSSION OF REQUIREMENTS FOR ALPINE DATED 9/26/01. ALL MWD LOG HEADER DATA RETAIN ORIGINAL DRILLERS DEPTH REFERENCE. 7. MWD RUNS 1 - 4 REPRESENT WELL CD2-45 WITH API # 50-103-20395-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13402' MD, 7138' TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (DEEP SPACING) . SFXE SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name............ .STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/02 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE FET RPD RPM RPS RPX GR ROP $ 1 and clipped curves¡ all bit runs merged. .5000 START DEPTH 2726.0 2726.0 2726.0 2726.0 2726.0 2734.5 2774.5 STOP DEPTH 13344.5 13344.5 13344.5 13344.5 13344.5 13337.5 13402.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD BIT RUN NO 2 3 4 MERGE TOP 2726.0 9927.0 9974.5 MERGE BASE 9982.0 10038.5 13402.0 $ ) ) # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2726 13402 8064 21353 2726 13402 ROP MWD FT/H 0.01 441.12 139.991 21227 2774.5 13402 GR MWD API 29.47 376.15 92.3531 21207 2734.5 13337.5 RPX MWD OHMM 0.43 2000 11.1433 21238 2726 13344.5 RPS MWD OHMM 0.06 2000 11.0933 21238 2726 13344.5 RPM MWD OHMM 0.16 2000 15.3607 21238 2726 13344.5 RPD MWD OHMM 0.14 2000 22.8197 21238 2726 13344.5 FET MWD HOUR 0.2119 9637.38 37.5576 21238 2726 13344.5 First Reading For Entire File......... .2726 Last Reading For Entire File.......... .13402 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/02 Maximum Physical Record. .65535 File Type................ LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/02 Maximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ '\ .J 2 ) header data for each bit run in separate files. 2 .5000 START DEPTH 2726.0 2726.0 2726.0 2726.0 2726.0 2734.5 2774.5 STOP DEPTH 9933.5 9933.5 9933.5 9933.5 9933.5 9941.0 9982.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O 22-NOV-01 Insite 66.16 Memory 9982.0 2734.0 9982.0 42.8 89.6 TOOL NUMBER 136693 134759 8.500 2764.0 LSND 9.60 40.0 9.4 300 3.6 1.400 .720 1.300 2.000 70.0 141.8 70.0 70.0 Data Specification Block ~je.....o Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2726 9982 6354 14513 2726 9982 ROP MWD020 FT/H 0.01 441.12 154.742 14389 2774.5 9982 GR MWD020 API 43.27 376.15 111.539 14414 2734.5 9941 RPX MWD020 OHMM 0.43 2000 5.66104 14416 2726 9933.5 RPS MWD020 OHMM 0.06 2000 5.78247 14416 2726 9933.5 RPM MWD020 OHMM 0.16 2000 7.14723 14416 2726 9933.5 RPD MWD020 OHMM 0.14 2000 13.2588 14416 2726 9933.5 FET MWD020 HOUR 0.2119 55.5995 1.30903 14416 2726 9933.5 First Reading For Entire File......... .2726 Last Reading For Entire File.......... .9982 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/02 Maximum Physical Record. .65535 File Type................LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/02 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # 3 header data for each bit run in separate files. 3 .5000 FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ ") START DEPTH 9927.0 9934.0 9934.0 9934.0 9934.0 9934.0 9982.5 STOP DEPTH 9993.0 10000.0 10000.0 10000.0 10000.0 10000.0 10038.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 ) 26-NOV-01 Insite 66.16 Memory 10038.0 9982.0 10038.0 .0 .0 TOOL NUMBER 151107 156404 6.125 9972.0 MOBM 9.20 81.0 .0 160000 1.0 .000 .000 .000 .000 .0 156.2 .0 .0 Depth Uni t s . . . . . . . . . . . . . . ) ) )'. . . . . . . Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9927 10038.5 9982.75 224 9927 10038.5 ROP MWD030 FT/H 5.12 111.89 72.3758 113 9982.5 10038.5 GR MWD030 API 29.47 54.8 39.0471 133 9927 9993 RPX MWD030 OHMM 2.71 1874.65 22.9952 133 9934 10000 RPS MWD030 OHMM 3.95 1722.54 32.4573 133 9934 10000 RPM MWD030 OHMM 0.4 2000 607.115 133 9934 10000 RPD MWD030 OHMM 11.94 2000 1077.14 133 9934 10000 FET MWD030 HOUR 23.84 99.79 70.5539 133 9934 10000 First Reading For Entire File......... .9927 Last Reading For Entire File.......... .10038.5 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/02 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/02 Maximum Physical Record. .65535 F i 1 e Type................ LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX 4 header data for each bit run in separate files. 4 .5000 START DEPTH 9974.5 9981.0 9981.0 9981.0 9981.0 STOP DEPTH 13337.5 13344.5 13344.5 13344.5 13344.5 FET ROP $ 9981.0 10039.0 ') 13344.5 13402.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction............... ..Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) , 03-JAN-03 Insite 66.37 Memory 13402.0 10038.0 13402.0 88.9 93.0 TOOL NUMBER 151107 156401 6.125 9972.0 MOBM 8.90 61.0 .0 29000 4.0 .000 .000 .000 .000 .0 151.0 .0 .0 Name Service Order DEPT ROP MWD040 GR MWD040 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 ) ) ¡. RPX MWD040 OHMM 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9974.5 13402 11688.3 6856 9974.5 13402 ROP MWD040 FT/H 0.29 310.38 109.566 6725 10039 13402 GR MWD040 API 29.97 93.51 51.8051 6727 9974.5 13337.5 RPX MWD040 OHMM 6.03 62.2 22.6475 6728 9981 13344.5 RPS MWD040 OHMM 7.1 55.53 22.0477 6728 9981 13344.5 RPM MWD040 OHMM 7.05 76.71 21.2408 6728 9981 13344.5 RPD MWD040 OHMM 7.92 79.38 22.4126 6728 9981 13344.5 FET MWD040 HOUR 0.27 9713.3 170.299 6728 9981 13344.5 First Reading For Entire File......... .9974.5 Last Reading For Entire File.......... .13402 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/02 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . . 03/06/02 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... .UNKNOWN Continuation Number..... .01 Next Tape Name.......... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03/06/02 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File